10-Q

    Table of Contents                                Index to Financial Statements

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2022

OR

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d)

OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from           to            

Commission
File Number Registrant,
State of Incorporation,
Address and Telephone Number I.R.S. Employer
Identification No.

1-3526 The Southern Company 58-0690070

(A Delaware Corporation)

30 Ivan Allen Jr. Boulevard, N.W.

Atlanta, Georgia 30308

(404) 506-5000

1-3164 Alabama Power Company 63-0004250

(An Alabama Corporation)

600 North 18th Street

Birmingham, Alabama 35203

(205) 257-1000

1-6468 Georgia Power Company 58-0257110

(A Georgia Corporation)

241 Ralph McGill Boulevard, N.E.

Atlanta, Georgia 30308

(404) 506-6526

001-11229 Mississippi Power Company 64-0205820

(A Mississippi Corporation)

2992 West Beach Boulevard

Gulfport, Mississippi 39501

(228) 864-1211

001-37803 Southern Power Company 58-2598670

(A Delaware Corporation)

30 Ivan Allen Jr. Boulevard, N.W.

Atlanta, Georgia 30308

(404) 506-5000

1-14174 Southern Company Gas 58-2210952

(A Georgia Corporation)

Ten Peachtree Place, N.E.

Atlanta, Georgia 30309

(404) 584-4000

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Securities registered pursuant to Section 12(b) of the Act:

Registrant	Title of Each Class	Trading Symbol(s)	Name of Each Exchange on Which Registered
The Southern Company	Common Stock, par value $5 per share	SO	New York Stock Exchange
			(NYSE)
The Southern Company	Series 2017B 5.25% Junior Subordinated Notes due 2077	SOJC	NYSE
The Southern Company	2019 Series A Corporate Units	SOLN	NYSE
The Southern Company	Series 2020A 4.95% Junior Subordinated Notes due 2080	SOJD	NYSE
The Southern Company	Series 2020C 4.20% Junior Subordinated Notes due 2060	SOJE	NYSE
The Southern Company	Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081	SO 81	NYSE
Alabama Power Company	5.00% Series Class A Preferred Stock	ALP PR Q	NYSE
Georgia Power Company	Series 2017A 5.00% Junior Subordinated Notes due 2077	GPJA	NYSE
Southern Power Company	Series 2016A 1.000% Senior Notes due 2022	SO/22B	NYSE
Southern Power Company	Series 2016B 1.850% Senior Notes due 2026	SO/26A	NYSE

Indicate by check mark whether the registrants (1) have filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrants were required to file such reports), and (2) have been subject to such filing requirements for the past 90 days. Yes þ No ¨

Indicate by check mark whether the registrants have submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T during the preceding 12 months (or for such shorter period that the registrants were required to submit such files). Yes þ No ¨

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of "large accelerated filer," "accelerated filer," "smaller reporting company," and "emerging growth company" in Rule 12b-2 of the Exchange Act.

Registrant	Large Accelerated Filer	Accelerated Filer	Non-accelerated Filer	Smaller Reporting Company	Emerging Growth Company
The Southern Company	X
Alabama Power Company			X
Georgia Power Company			X
Mississippi Power Company			X
Southern Power Company			X
Southern Company Gas			X

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No þ (Response applicable to all registrants.)

Registrant	Description of Common Stock	Shares Outstanding at March 31, 2022
The Southern Company	Par Value $5 Per Share	1,062,524,675
Alabama Power Company	Par Value $40 Per Share	30,537,500
Georgia Power Company	Without Par Value	9,261,500
Mississippi Power Company	Without Par Value	1,121,000
Southern Power Company	Par Value $0.01 Per Share	1,000
Southern Company Gas	Par Value $0.01 Per Share	100

This combined Form 10-Q is separately filed by The Southern Company, Alabama Power Company, Georgia Power Company, Mississippi Power Company, Southern Power Company, and Southern Company Gas. Information contained herein relating to any individual registrant is filed by such registrant on its own behalf. Each registrant makes no representation as to information relating to the other registrants.

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TABLE OF CONTENTS

		Page
	Definitions	4
	Cautionary Statement Regarding Forward-Looking Information	7
	PART I—FINANCIAL INFORMATION
Item 1.	Financial Statements (Unaudited)	9
Item 2.	Management's Discussion and Analysis of Financial Condition and Results of Operations	86
Item 3.	Quantitative and Qualitative Disclosures about Market Risk	128
Item 4.	Controls and Procedures	128
	PART II—OTHER INFORMATION
Item 1.	Legal Proceedings	129
Item 1A.	Risk Factors	129
Item 2.	Unregistered Sales of Equity Securities and Use of Proceeds	Inapplicable
Item 3.	Defaults Upon Senior Securities	Inapplicable
Item 4.	Mine Safety Disclosures	Inapplicable
Item 5.	Other Information	Inapplicable
Item 6.	Exhibits	129
	Signatures	132

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DEFINITIONS

Term	Meaning
2019 ARP	Alternate Rate Plan approved by the Georgia PSC in 2019 for Georgia Power for the years 2020 through 2022
AFUDC	Allowance for funds used during construction
Alabama Power	Alabama Power Company
Amended and Restated Loan Guarantee Agreement	Loan guarantee agreement entered into by Georgia Power with the DOE in 2014, as amended and restated in March 2019, under which the proceeds of borrowings may be used to reimburse Georgia Power for Eligible Project Costs incurred in connection with its construction of Plant Vogtle Units 3 and 4
ARO	Asset retirement obligation
Atlanta Gas Light	Atlanta Gas Light Company, a wholly-owned subsidiary of Southern Company Gas
Bechtel	Bechtel Power Corporation, the primary contractor for the remaining construction activities for Plant Vogtle Units 3 and 4
Bechtel Agreement	The 2017 construction completion agreement between the Vogtle Owners and Bechtel
CCR	Coal combustion residuals
Chattanooga Gas	Chattanooga Gas Company, a wholly-owned subsidiary of Southern Company Gas
COD	Commercial operation date
Contractor Settlement Agreement	The December 31, 2015 agreement between Westinghouse and the Vogtle Owners resolving disputes between the Vogtle Owners and the EPC Contractor under the Vogtle 3 and 4 Agreement
COVID-19	The novel coronavirus disease declared a pandemic by the World Health Organization and the Centers for Disease Control and Prevention in March 2020
CWIP	Construction work in progress
Dalton	City of Dalton, Georgia, an incorporated municipality in the State of Georgia, acting by and through its Board of Water, Light, and Sinking Fund Commissioners
Dalton Pipeline	A pipeline facility in Georgia in which Southern Company Gas has a 50% undivided ownership interest
DOE	U.S. Department of Energy
ECCR	Georgia Power's Environmental Compliance Cost Recovery tariff
Eligible Project Costs	Certain costs of construction relating to Plant Vogtle Units 3 and 4 that are eligible for financing under the loan guarantee program established under Title XVII of the Energy Policy Act of 2005
EPA	U.S. Environmental Protection Agency
EPC Contractor	Westinghouse and its affiliate, WECTEC Global Project Services Inc.; the former engineering, procurement, and construction contractor for Plant Vogtle Units 3 and 4
FERC	Federal Energy Regulatory Commission
FFB	Federal Financing Bank
Fitch	Fitch Ratings, Inc.
Form 10-K	Annual Report on Form 10-K of Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas for the year ended December 31, 2021, as applicable
GAAP	U.S. generally accepted accounting principles
Georgia Power	Georgia Power Company
Guarantee Settlement Agreement	The June 9, 2017 settlement agreement between the Vogtle Owners and Toshiba related to certain payment obligations of the EPC Contractor guaranteed by Toshiba
Gulf Power	Gulf Power Company, until January 1, 2019 a wholly-owned subsidiary of Southern Company; effective January 1, 2021, Gulf Power Company merged with and into Florida Power and Light Company, with Florida Power and Light Company remaining as the surviving company
Heating Degree Days	A measure of weather, calculated when the average daily temperatures are less than 65 degrees Fahrenheit
Heating Season	The period from November through March when Southern Company Gas' natural gas usage and operating revenues are generally higher

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DEFINITIONS

(continued)

Term	Meaning
HLBV	Hypothetical liquidation at book value
IGCC	Integrated coal gasification combined cycle, the technology originally approved for Mississippi Power's Kemper County energy facility
IIC	Intercompany Interchange Contract
ITAAC	Inspections, Tests, Analyses, and Acceptance Criteria, standards established by the NRC
ITC	Investment tax credit
JEA	Jacksonville Electric Authority
KWH	Kilowatt-hour
LIBOR	London Interbank Offered Rate
LIFO	Last-in, first-out
LOCOM	Lower of weighted average cost or current market price
LTSA	Long-term service agreement
MEAG Power	Municipal Electric Authority of Georgia
Mississippi Power	Mississippi Power Company
mmBtu	Million British thermal units
Moody's	Moody's Investors Service, Inc.
MW	Megawatt
natural gas distribution utilities	Southern Company Gas' natural gas distribution utilities (Nicor Gas, Atlanta Gas Light, Virginia Natural Gas, and Chattanooga Gas)
NCCR	Georgia Power's Nuclear Construction Cost Recovery tariff
NDR	Alabama Power's Natural Disaster Reserve
Nicor Gas	Northern Illinois Gas Company, a wholly-owned subsidiary of Southern Company Gas
NRC	U.S. Nuclear Regulatory Commission
NYMEX	New York Mercantile Exchange, Inc.
OCI	Other comprehensive income
PennEast Pipeline	PennEast Pipeline Company, LLC, a joint venture in which Southern Company Gas has a 20% ownership interest
PEP	Mississippi Power's Performance Evaluation Plan
PowerSecure	PowerSecure, Inc., a wholly-owned subsidiary of Southern Company
PPA	Power purchase agreements, as well as, for Southern Power, contracts for differences that provide the owner of a renewable facility a certain fixed price for the electricity sold to the grid
PSC	Public Service Commission
PTC	Production tax credit
Rate CNP	Alabama Power's Rate Certificated New Plant, consisting of Rate CNP New Plant, Rate CNP Compliance, and Rate CNP PPA
Rate ECR	Alabama Power's Rate Energy Cost Recovery
Rate RSE	Alabama Power's Rate Stabilization and Equalization
Registrants	Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power Company, and Southern Company Gas
ROE	Return on equity
S&P	S&P Global Ratings, a division of S&P Global Inc.
SCS	Southern Company Services, Inc., the Southern Company system service company and a wholly-owned subsidiary of Southern Company
SEC	U.S. Securities and Exchange Commission
SEGCO	Southern Electric Generating Company, 50% owned by each of Alabama Power and Georgia Power

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DEFINITIONS

(continued)

Term	Meaning
Sequent	Sequent Energy Management, L.P. and Sequent Energy Canada Corp., wholly-owned subsidiaries of Southern Company Gas through June 30, 2021
SNG	Southern Natural Gas Company, L.L.C., a pipeline system in which Southern Company Gas has a 50% ownership interest
SOFR	Secured Overnight Financing Rate
Southern Company	The Southern Company
Southern Company Gas	Southern Company Gas and its subsidiaries
Southern Company Gas Capital	Southern Company Gas Capital Corporation, a 100%-owned subsidiary of Southern Company Gas
Southern Company power pool	The operating arrangement whereby the integrated generating resources of the traditional electric operating companies and Southern Power (excluding subsidiaries) are subject to joint commitment and dispatch in order to serve their combined load obligations
Southern Company system	Southern Company, the traditional electric operating companies, Southern Power, Southern Company Gas, SEGCO, Southern Nuclear, SCS, Southern Communications Services, Inc., PowerSecure, and other subsidiaries
Southern Nuclear	Southern Nuclear Operating Company, Inc., a wholly-owned subsidiary of Southern Company
Southern Power	Southern Power Company and its subsidiaries
SouthStar	SouthStar Energy Services, LLC (a Marketer), a wholly-owned subsidiary of Southern Company Gas
SP Solar	SP Solar Holdings I, LP, a limited partnership indirectly owning substantially all of Southern Power's solar and battery energy storage facilities, in which Southern Power has a 67% ownership interest
SP Wind	SP Wind Holdings II, LLC, a holding company owning a portfolio of eight operating wind facilities, in which Southern Power is the controlling partner in a tax equity arrangement
Subsidiary Registrants	Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas
Toshiba	Toshiba Corporation, the parent company of Westinghouse
traditional electric operating companies	Alabama Power, Georgia Power, and Mississippi Power
VCM	Vogtle Construction Monitoring
VIE	Variable interest entity
Virginia Natural Gas	Virginia Natural Gas, Inc., a wholly-owned subsidiary of Southern Company Gas
Vogtle 3 and 4 Agreement	Agreement entered into with the EPC Contractor in 2008 by Georgia Power, acting for itself and as agent for the Vogtle Owners, and rejected in bankruptcy in July 2017, pursuant to which the EPC Contractor agreed to design, engineer, procure, construct, and test Plant Vogtle Units 3 and 4
Vogtle Owners	Georgia Power, Oglethorpe Power Corporation, MEAG Power, and Dalton
Vogtle Services Agreement	The June 2017 services agreement between the Vogtle Owners and the EPC Contractor, as amended and restated in July 2017, for the EPC Contractor to transition construction management of Plant Vogtle Units 3 and 4 to Southern Nuclear and to provide ongoing design, engineering, and procurement services to Southern Nuclear
WACOG	Weighted average cost of gas
Westinghouse	Westinghouse Electric Company LLC

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

This Quarterly Report on Form 10-Q contains forward-looking statements. Forward-looking statements include, among other things, statements concerning the potential and expected effects of the continued COVID-19 pandemic, regulated rates, the strategic goals for the business, customer and sales growth, economic conditions, cost recovery and other rate actions, projected equity ratios, current and proposed environmental regulations and related compliance plans and estimated expenditures, pending or potential litigation matters, access to sources of capital, financing activities, completion dates and costs of construction projects, matters related to the abandonment of the Kemper IGCC, completion of announced acquisitions, filings with state and federal regulatory authorities, and estimated construction plans and expenditures. In some cases, forward-looking statements can be identified by terminology such as "may," "will," "could," "would," "should," "expects," "plans," "anticipates," "believes," "estimates," "projects," "predicts," "potential," or "continue" or the negative of these terms or other similar terminology. There are various factors that could cause actual results to differ materially from those suggested by the forward-looking statements; accordingly, there can be no assurance that such indicated results will be realized. These factors include:

•the impact of recent and future federal and state regulatory changes, including tax, environmental, and other laws and regulations to which Southern Company and its subsidiaries are subject, as well as changes in application of existing laws and regulations;

•the potential effects of the continued COVID-19 pandemic, including, but not limited to, those described in Item 1A "Risk Factors" of the Form 10-K;

•the extent and timing of costs and legal requirements related to CCR;

•current and future litigation or regulatory investigations, proceedings, or inquiries, including litigation and other disputes related to the Kemper County energy facility;

•the effects, extent, and timing of the entry of additional competition in the markets in which Southern Company's subsidiaries operate, including from the development and deployment of alternative energy sources;

•variations in demand for electricity and natural gas;

•available sources and costs of natural gas and other fuels and commodities;

•the ability to complete necessary or desirable pipeline expansion or infrastructure projects, limits on pipeline capacity, and operational interruptions to natural gas distribution and transmission activities;

•transmission constraints;

•effects of inflation;

•the ability to control costs and avoid cost and schedule overruns during the development, construction, and operation of facilities or other projects, including Plant Vogtle Units 3 and 4 (which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale) and Plant Barry Unit 8, due to current and/or future challenges which include, but are not limited to, changes in labor costs, availability, and productivity; challenges with management of contractors or vendors; subcontractor performance; adverse weather conditions; shortages, delays, increased costs, or inconsistent quality of equipment, materials, and labor; contractor or supplier delay; delays due to judicial or regulatory action; nonperformance under construction, operating, or other agreements; operational readiness, including specialized operator training and required site safety programs; engineering or design problems or any remediation related thereto; design and other licensing-based compliance matters, including, for nuclear units, inspections and the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related investigations, reviews, and approvals by the NRC necessary to support NRC authorization to load fuel; challenges with start-up activities, including major equipment failure, or system integration; and/or operational performance; and challenges related to the COVID-19 pandemic;

•the ability to overcome or mitigate the current challenges at Plant Vogtle Units 3 and 4, as described in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" in Item 1 herein, that could further impact the cost and schedule for the project;

•legal proceedings and regulatory approvals and actions related to construction projects, such as Plant Vogtle Units 3 and 4 and Plant Barry Unit 8, including PSC approvals and FERC and NRC actions;

•under certain specified circumstances, a decision by holders of more than 10% of the ownership interests of Plant Vogtle Units 3 and 4 not to proceed with construction and the ability of other Vogtle Owners to tender a portion of their ownership interests to Georgia Power following certain construction cost increases;

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CAUTIONARY STATEMENT REGARDING FORWARD-LOOKING INFORMATION

(continued)

•in the event Georgia Power becomes obligated to provide funding to MEAG Power with respect to the portion of MEAG Power's ownership interest in Plant Vogtle Units 3 and 4 involving JEA, any inability of Georgia Power to receive repayment of such funding;

•the ability to construct facilities in accordance with the requirements of permits and licenses (including satisfaction of NRC requirements), to satisfy any environmental performance standards and the requirements of tax credits and other incentives, and to integrate facilities into the Southern Company system upon completion of construction;

•investment performance of the employee and retiree benefit plans and nuclear decommissioning trust funds;

•advances in technology, including the pace and extent of development of low- to no-carbon energy technologies and negative carbon concepts;

•performance of counterparties under ongoing renewable energy partnerships and development agreements;

•state and federal rate regulations and the impact of pending and future rate cases and negotiations, including rate actions relating to ROE, equity ratios, additional generating capacity, and fuel and other cost recovery mechanisms;

•the ability to successfully operate the traditional electric operating companies' and SEGCO's generation, transmission, and distribution facilities, Southern Power's generation facilities, and Southern Company Gas' natural gas distribution and storage facilities and the successful performance of necessary corporate functions;

•the inherent risks involved in operating and constructing nuclear generating facilities;

•the inherent risks involved in transporting and storing natural gas;

•the performance of projects undertaken by the non-utility businesses and the success of efforts to invest in and develop new opportunities;

•internal restructuring or other restructuring options that may be pursued;

•potential business strategies, including acquisitions or dispositions of assets or businesses, which cannot be assured to be completed or beneficial to Southern Company or its subsidiaries;

•the ability of counterparties of Southern Company and its subsidiaries to make payments as and when due and to perform as required;

•the ability to obtain new short- and long-term contracts with wholesale customers;

•the direct or indirect effect on the Southern Company system's business resulting from cyber intrusion or physical attack and the threat of physical attacks;

•interest rate fluctuations and financial market conditions and the results of financing efforts;

•access to capital markets and other financing sources;

•changes in Southern Company's and any of its subsidiaries' credit ratings;

•the replacement of LIBOR with an alternative reference rate;

•the ability of the traditional electric operating companies to obtain additional generating capacity (or sell excess generating capacity) at competitive prices;

•catastrophic events such as fires, earthquakes, explosions, floods, tornadoes, hurricanes and other storms, droughts, pandemic health events, political unrest, wars, or other similar occurrences;

•the direct or indirect effects on the Southern Company system's business resulting from incidents affecting the U.S. electric grid, natural gas pipeline infrastructure, or operation of generating or storage resources;

•impairments of goodwill or long-lived assets;

•the effect of accounting pronouncements issued periodically by standard-setting bodies; and

•other factors discussed elsewhere herein and in other reports (including the Form 10-K) filed by the Registrants from time to time with the SEC.

The Registrants expressly disclaim any obligation to update any forward-looking statements.

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PART I

Item 1. Financial Statements (Unaudited).

	Page
The Southern Company and Subsidiary Companies:
Condensed Consolidated Statements of Income	10
Condensed Consolidated Statements of Comprehensive Income	11
Condensed Consolidated Statements of Cash Flows	12
Condensed Consolidated Balance Sheets	13
Condensed Consolidated Statements of Stockholders' Equity	15
Alabama Power Company:
Condensed Statements of Income	16
Condensed Statements of Comprehensive Income	16
Condensed Statements of Cash Flows	17
Condensed Balance Sheets	18
Condensed Statements of Common Stockholder's Equity	20
Georgia Power Company:
Condensed Statements of Income	21
Condensed Statements of Comprehensive Income	21
Condensed Statements of Cash Flows	22
Condensed Balance Sheets	23
Condensed Statements of Common Stockholder's Equity	25
Mississippi Power Company:
Condensed Statements of Income and Comprehensive Income	26
Condensed Statements of Cash Flows	27
Condensed Balance Sheets	28
Condensed Statements of Common Stockholder's Equity	30
Southern Power Company and Subsidiary Companies:
Condensed Consolidated Statements of Income	31
Condensed Consolidated Statements of Comprehensive Income	31
Condensed Consolidated Statements of Cash Flows	32
Condensed Consolidated Balance Sheets	33
Condensed Consolidated Statements of Stockholders' Equity	35
Southern Company Gas and Subsidiary Companies:
Condensed Consolidated Statements of Income	36
Condensed Consolidated Statements of Comprehensive Income	36
Condensed Consolidated Statements of Cash Flows	37
Condensed Consolidated Balance Sheets	38
Condensed Consolidated Statements of Stockholder's Equity	40
Combined Notes to the Condensed Financial Statements	41

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Retail electric revenues	$	3,613	$	3,342
Wholesale electric revenues	664		545
Other electric revenues	177		170
Natural gas revenues (includes alternative revenue programs of $— and $2, respectively)	2,058		1,694
Other revenues	136		159
Total operating revenues	6,648		5,910
Operating Expenses:
Fuel	1,111		848
Purchased power	232		207
Cost of natural gas	1,095		583
Cost of other sales	69		82
Other operations and maintenance	1,516		1,372
Depreciation and amortization	892		871
Taxes other than income taxes	372		345
Estimated loss on Plant Vogtle Units 3 and 4	—		48
Gain on dispositions, net	(23)		(44)
Total operating expenses	5,264		4,312
Operating Income	1,384		1,598
Other Income and (Expense):
Allowance for equity funds used during construction	51		46
Earnings from equity method investments	46		45
Interest expense, net of amounts capitalized	(462)		(450)
Other income (expense), net	145		58
Total other income and (expense)	(220)		(301)
Earnings Before Income Taxes	1,164		1,297
Income taxes	173		190
Consolidated Net Income	991		1,107
Dividends on preferred stock of subsidiaries	4		4
Net loss attributable to noncontrolling interests	(45)		(32)
Consolidated Net Income Attributable to    Southern Company	$	1,032	$	1,135
Common Stock Data:
Earnings per share -
Basic	$	0.97	$	1.07
Diluted	$	0.97	$	1.06
Average number of shares of common stock outstanding (in millions)
Basic	1,063		1,060
Diluted	1,069		1,066

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Consolidated Net Income	$	991	$	1,107
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $8 and $(10), respectively	19		(30)
Reclassification adjustment for amounts included in net income,    net of tax of $6 and $18, respectively	20		55
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income,    net of tax of $1 and $1, respectively	3		3
Total other comprehensive income	42		28
Comprehensive Income	1,033		1,135
Dividends on preferred stock of subsidiaries	4		4
Comprehensive loss attributable to noncontrolling interests	(45)		(32)
Consolidated Comprehensive Income Attributable to    Southern Company	$	1,074	$	1,163

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Consolidated net income	$	991	$	1,107
Adjustments to reconcile consolidated net income to net cash provided from operating activities —
Depreciation and amortization, total	989		964
Deferred income taxes	40		140
Allowance for equity funds used during construction	(51)		(46)
Pension, postretirement, and other employee benefits	(123)		(78)
Settlement of asset retirement obligations	(87)		(109)
Stock based compensation expense	85		83
Estimated loss on Plant Vogtle Units 3 and 4	—		48
Storm damage accruals	52		54
Gain on dispositions, net	(20)		(41)
Natural gas cost under recovery – long-term	162		(185)
Retail fuel cost under recovery – long-term	(130)		—
Other, net	7		114
Changes in certain current assets and liabilities —
-Receivables	(217)		308
-Prepayments	(86)		(98)
-Materials and supplies	(28)		(27)
-Natural gas for sale, net of temporary LIFO liquidation	450		456
-Natural gas cost under recovery	(40)		(487)
-Other current assets	87		90
-Accounts payable	132		(216)
-Accrued taxes	(58)		(212)
-Accrued compensation	(470)		(417)
-Accrued interest	(128)		(90)
-Retail fuel cost over recovery	—		(53)
-Other current liabilities	35		(63)
Net cash provided from operating activities	1,592		1,242
Investing Activities:
Business acquisitions, net of cash acquired	—		(345)
Property additions	(1,419)		(1,678)
Nuclear decommissioning trust fund purchases	(294)		(550)
Nuclear decommissioning trust fund sales	289		546
Cost of removal, net of salvage	(227)		(85)
Change in construction payables, net	23		(116)
Payments pursuant to LTSAs	(37)		(60)
Other investing activities	110		45
Net cash used for investing activities	(1,555)		(2,243)
Financing Activities:
Increase in notes payable, net	137		182
Proceeds —
Long-term debt	700		2,150
Short-term borrowings	850		325
Common stock	38		14
Redemptions and repurchases —
Long-term debt	(977)		(384)
Short-term borrowings	(100)		(25)
Capital contributions from noncontrolling interests	73		313
Distributions to noncontrolling interests	(97)		(46)
Payment of common stock dividends	(702)		(678)
Other financing activities	(115)		(117)
Net cash provided from (used for) financing activities	(193)		1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)		733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829		1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,673	$	1,801
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $23 and $21 capitalized for 2022 and 2021, respectively)	$	515	$	519
Income taxes, net	(8)		(51)
Noncash transactions —
Accrued property additions at end of period	863		872
Contributions from noncontrolling interests	—		89
Contributions of wind turbine equipment	—		82
Right-of-use assets obtained under leases	3		76
Reassessment of right-of-use assets under operating leases	40		—

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,662	$	1,798
Receivables —
Customer accounts	2,006		1,806
Unbilled revenues	638		711
Other accounts and notes	509		523
Accumulated provision for uncollectible accounts	(89)		(78)
Materials and supplies	1,571		1,543
Fossil fuel for generation	411		450
Natural gas for sale	121		362
Prepaid expenses	739		330
Assets from risk management activities, net of collateral	405		151
Regulatory assets – asset retirement obligations	241		219
Natural gas cost under recovery	306		266
Other regulatory assets	576		653
Other current assets	201		231
Total current assets	9,297		8,965
Property, Plant, and Equipment:
In service	116,259		115,592
Less: Accumulated depreciation	34,645		34,079
Plant in service, net of depreciation	81,614		81,513
Nuclear fuel, at amortized cost	839		824
Construction work in progress	9,337		8,771
Total property, plant, and equipment	91,790		91,108
Other Property and Investments:
Goodwill	5,280		5,280
Nuclear decommissioning trusts, at fair value	2,403		2,542
Equity investments in unconsolidated subsidiaries	1,293		1,282
Other intangible assets, net of amortization of $317 and $307, respectively	435		445
Miscellaneous property and investments	633		653
Total other property and investments	10,044		10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693		1,701
Deferred charges related to income taxes	833		824
Prepaid pension costs	1,772		1,657
Unamortized loss on reacquired debt	257		258
Regulatory assets – asset retirement obligations, deferred	5,683		5,466
Other regulatory assets, deferred	5,372		5,577
Other deferred charges and assets	1,898		1,776
Total deferred charges and other assets	17,508		17,259
Total Assets	$	128,639	$	127,534

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholders' Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	1,193	$	2,157
Notes payable	2,330		1,440
Accounts payable	2,251		2,169
Customer deposits	454		479
Accrued taxes —
Accrued income taxes	57		50
Other accrued taxes	415		641
Accrued interest	404		533
Accrued compensation	574		1,070
Asset retirement obligations	695		697
Operating lease obligations	245		250
Other regulatory liabilities	711		563
Other current liabilities	1,105		872
Total current liabilities	10,434		10,921
Long-term Debt	50,633		50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506		8,862
Deferred credits related to income taxes	5,365		5,401
Accumulated deferred ITCs	2,196		2,216
Employee benefit obligations	1,526		1,550
Operating lease obligations, deferred	1,521		1,503
Asset retirement obligations, deferred	11,016		10,990
Other cost of removal obligations	2,030		2,103
Other regulatory liabilities, deferred	526		485
Other deferred credits and liabilities	966		816
Total deferred credits and other liabilities	34,652		33,926
Total Liabilities	95,719		94,967
Redeemable Preferred Stock of Subsidiaries	291		291
Total Stockholders' Equity (See accompanying statements)	32,629		32,276
Total Liabilities and Stockholders' Equity	$	128,639	$	127,534

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED)

	Southern Company Common Stockholders' Equity
	Number of Common Shares		Common Stock								Accumulated Other Comprehensive Income (Loss)
	Issued	Treasury	Par Value		Paid-In Capital		Treasury		Retained Earnings				Noncontrolling Interests		Total
	(in millions)
Balance at December 31, 2020	1,058	(1)	$	5,268	$	11,834	$	(46)	$	11,311	$	(395)	$	4,262	$	32,234
Consolidated net income (loss)	—	—	—		—		—		1,135		—		(32)		1,103
Other comprehensive income	—	—	—		—		—		—		28		—		28
Stock issued	2	—	5		9		—		—		—		—		14
Stock-based compensation	—	—	—		9		—		—		—		—		9
Cash dividends of $0.64 per share	—	—	—		—		—		(678)		—		—		(678)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		403		403
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(46)		(46)
Other	—	—	—		2		—		—		—		(1)		1
Balance at March 31, 2021	1,060	(1)	$	5,273	$	11,854	$	(46)	$	11,768	$	(367)	$	4,586	$	33,068

Balance at December 31, 2021	1,061	(1)	$	5,279	$	11,950	$	(47)	$	10,929	$	(237)	$	4,402	$	32,276
Consolidated net income (loss)	—	—	—		—		—		1,032		—		(45)		987
Other comprehensive income	—	—	—		—		—		—		42		—		42
Stock issued	3	—	7		31		—		—		—		—		38
Stock-based compensation	—	—	—		6		—		—		—		—		6
Cash dividends of $0.66 per share	—	—	—		—		—		(702)		—		—		(702)
Capital contributions from    noncontrolling interests	—	—	—		—		—		—		—		73		73
Distributions to noncontrolling interests	—	—	—		—		—		—		—		(98)		(98)
Other	—	—	—		7		(2)		2		—		—		7
Balance at March 31, 2022	1,064	(1)	$	5,286	$	11,994	$	(49)	$	11,261	$	(195)	$	4,332	$	32,629

The accompanying notes as they relate to Southern Company are an integral part of these condensed consolidated financial statements.

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ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Retail revenues	$	1,379	$	1,352
Wholesale revenues, non-affiliates	114		92
Wholesale revenues, affiliates	65		32
Other revenues	91		83
Total operating revenues	1,649		1,559
Operating Expenses:
Fuel	333		291
Purchased power, non-affiliates	67		50
Purchased power, affiliates	26		30
Other operations and maintenance	409		361
Depreciation and amortization	215		211
Taxes other than income taxes	104		103
Total operating expenses	1,154		1,046
Operating Income	495		513
Other Income and (Expense):
Allowance for equity funds used during construction	16		12
Interest expense, net of amounts capitalized	(89)		(84)
Other income (expense), net	36		32
Total other income and (expense)	(37)		(40)
Earnings Before Income Taxes	458		473
Income taxes	107		110
Net Income	351		363
Dividends on Preferred Stock	4		4
Net Income After Dividends on Preferred Stock	$	347	$	359

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Net Income	$	351	$	363
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $(1) and $—, respectively	(1)		—
Reclassification adjustment for amounts included in net income,    net of tax of $— and $—, respectively	1		1
Total other comprehensive income	—		1
Comprehensive Income	$	351	$	364

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	351	$	363
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	250		248
Deferred income taxes	35		33
Pension, postretirement, and other employee benefits	(48)		(29)
Settlement of asset retirement obligations	(38)		(49)
Retail fuel cost under recovery – long-term	(46)		—
Other, net	(27)		(14)
Changes in certain current assets and liabilities —
-Receivables	(4)		40
-Fossil fuel stock	23		38
-Prepayments	(85)		(73)
-Other current assets	(10)		(16)
-Accounts payable	(237)		(299)
-Accrued taxes	102		104
-Accrued compensation	(99)		(105)
-Retail fuel cost over recovery	—		(18)
-Other current liabilities	(13)		(9)
Net cash provided from operating activities	154		214
Investing Activities:
Property additions	(343)		(466)
Nuclear decommissioning trust fund purchases	(72)		(310)
Nuclear decommissioning trust fund sales	72		310
Cost of removal, net of salvage	(60)		(23)
Change in construction payables	39		32
Other investing activities	(1)		(9)
Net cash used for investing activities	(365)		(466)
Financing Activities:
Proceeds — Senior notes	700		—
Redemptions — Senior notes	(550)		—
Capital contributions from parent company	625		600
Payment of common stock dividends	(254)		(246)
Other financing activities	(17)		(13)
Net cash provided from financing activities	504		341
Net Change in Cash, Cash Equivalents, and Restricted Cash	293		89
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,060		530
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	1,353	$	619
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $4 and $3 capitalized for 2022 and 2021, respectively)	$	110	$	93
Noncash transactions —
Accrued property additions at end of period	188		198
Right-of-use assets obtained under leases	1		1

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	1,353	$	1,060
Receivables —
Customer accounts	417		410
Unbilled revenues	127		138
Affiliated	36		37
Other accounts and notes	64		55
Accumulated provision for uncollectible accounts	(15)		(14)
Fossil fuel stock	136		159
Materials and supplies	550		548
Prepaid expenses	126		41
Other regulatory assets	191		208
Other current assets	131		67
Total current assets	3,116		2,709
Property, Plant, and Equipment:
In service	33,333		33,135
Less: Accumulated provision for depreciation	10,451		10,313
Plant in service, net of depreciation	22,882		22,822
Nuclear fuel, at amortized cost	246		247
Construction work in progress	1,249		1,147
Total property, plant, and equipment	24,377		24,216
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,257		1,325
Equity investments in unconsolidated subsidiaries	57		57
Miscellaneous property and investments	126		126
Total other property and investments	1,440		1,508
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	97		108
Deferred charges related to income taxes	243		240
Prepaid pension and other postretirement benefit costs	546		513
Regulatory assets – asset retirement obligations	1,663		1,547
Other regulatory assets, deferred	1,717		1,807
Other deferred charges and assets	371		334
Total deferred charges and other assets	4,637		4,549
Total Assets	$	33,570	$	32,982

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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ALABAMA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	201	$	751
Accounts payable —
Affiliated	194		309
Other	372		459
Customer deposits	106		106
Accrued taxes	200		98
Accrued interest	77		100
Accrued compensation	124		219
Asset retirement obligations	322		320
Other regulatory liabilities	148		215
Other current liabilities	128		125
Total current liabilities	1,872		2,702
Long-term Debt	9,631		8,936
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,619		3,573
Deferred credits related to income taxes	1,959		1,968
Accumulated deferred ITCs	86		88
Employee benefit obligations	179		171
Operating lease obligations	64		66
Asset retirement obligations, deferred	4,013		4,014
Other cost of removal obligations	144		192
Other regulatory liabilities, deferred	224		210
Other deferred credits and liabilities	56		58
Total deferred credits and other liabilities	10,344		10,340
Total Liabilities	21,847		21,978
Redeemable Preferred Stock	291		291
Common Stockholder's Equity (See accompanying statements)	11,432		10,713
Total Liabilities and Stockholder's Equity	$	33,570	$	32,982

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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ALABAMA POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED)

	Number of Common Shares Issued	Common Stock		Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total
	(in millions)
Balance at December 31, 2020	31	$	1,222	$	5,413	$	3,194	$	(19)	$	9,810
Net income after dividends on    preferred stock	—	—		—		359		—		359
Capital contributions from parent company	—	—		602		—		—		602
Other comprehensive income	—	—		—		—		1		1
Cash dividends on common stock	—	—		—		(246)		—		(246)
Balance at March 31, 2021	31	$	1,222	$	6,015	$	3,307	$	(18)	$	10,526
Balance at December 31, 2021	31	$	1,222	$	6,056	$	3,448	$	(13)	$	10,713
Net income after dividends on    preferred stock	—	—		—		347		—		347
Capital contributions from parent company	—	—		626		—		—		626
Cash dividends on common stock	—	—		—		(254)		—		(254)
Balance at March 31, 2022	31	$	1,222	$	6,682	$	3,541	$	(13)	$	11,432

The accompanying notes as they relate to Alabama Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Retail revenues	$	2,017	$	1,787
Wholesale revenues	66		43
Other revenues	125		140
Total operating revenues	2,208		1,970
Operating Expenses:
Fuel	419		313
Purchased power, non-affiliates	150		144
Purchased power, affiliates	206		136
Other operations and maintenance	517		474
Depreciation and amortization	351		338
Taxes other than income taxes	125		116
Estimated loss on Plant Vogtle Units 3 and 4	—		48
Total operating expenses	1,768		1,569
Operating Income	440		401
Other Income and (Expense):
Allowance for equity funds used during construction	32		31
Interest expense, net of amounts capitalized	(107)		(104)
Other income (expense), net	50		41
Total other income and (expense)	(25)		(32)
Earnings Before Income Taxes	415		369
Income taxes	30		18
Net Income	$	385	$	351

CONDENSED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Net Income	$	385	$	351
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $3 and $—, respectively	9		—
Reclassification adjustment for amounts included in net income,    net of tax of $1 and $—, respectively	1		2
Total other comprehensive income	10		2
Comprehensive Income	$	395	$	353

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	385	$	351
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	397		384
Deferred income taxes	(6)		(86)
Pension, postretirement, and other employee benefits	(63)		(43)
Settlement of asset retirement obligations	(41)		(49)
Storm damage accruals	53		53
Retail fuel cost under recovery – long-term	(84)		—
Estimated loss on Plant Vogtle Units 3 and 4	—		48
Other, net	(85)		(19)
Changes in certain current assets and liabilities —
-Receivables	—		176
-Prepaid income taxes	(36)		—
-Other current assets	22		4
-Accounts payable	39		(74)
-Accrued taxes	(78)		(110)
-Accrued compensation	(79)		(68)
-Accrued interest	(43)		(34)
-Other current liabilities	(20)		(44)
Net cash provided from operating activities	361		489
Investing Activities:
Property additions	(749)		(775)
Nuclear decommissioning trust fund purchases	(221)		(241)
Nuclear decommissioning trust fund sales	217		236
Cost of removal, net of salvage	(140)		(40)
Change in construction payables, net of joint owner portion	14		(103)
Proceeds from dispositions	56		1
Other investing activities	14		9
Net cash used for investing activities	(809)		(913)
Financing Activities:
Increase in notes payable, net	410		145
Proceeds —
Senior notes	—		750
Short-term borrowings	450		—
Redemptions and repurchases —
Senior notes	(400)		(325)
FFB loan	(24)		(25)
Capital contributions from parent company	445		330
Payment of common stock dividends	(423)		(412)
Other financing activities	(17)		(19)
Net cash provided from financing activities	441		444
Net Change in Cash, Cash Equivalents, and Restricted Cash	(7)		20
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	33		9
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	26	$	29
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest (net of $16 and $15 capitalized for 2022 and 2021, respectively)	$	139	$	128
Noncash transactions —
Accrued property additions at end of period	459		445
Right-of-use assets obtained under operating leases	1		3

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	26	$	33
Receivables —
Customer accounts, net	561		547
Unbilled revenues	216		231
Joint owner accounts	60		116
Affiliated	12		25
Other accounts and notes	35		44
Fossil fuel stock	231		248
Materials and supplies	681		670
Regulatory assets – storm damage	4		48
Regulatory assets – asset retirement obligations	200		178
Assets from risk management activities	162		48
Other regulatory assets	248		241
Other current assets	124		130
Total current assets	2,560		2,559
Property, Plant, and Equipment:
In service	41,592		41,332
Less: Accumulated provision for depreciation	13,029		12,854
Plant in service, net of depreciation	28,563		28,478
Nuclear fuel, at amortized cost	593		577
Construction work in progress	7,086		6,688
Total property, plant, and equipment	36,242		35,743
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,146		1,217
Equity investments in unconsolidated subsidiaries	51		50
Miscellaneous property and investments	74		69
Total other property and investments	1,271		1,336
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,120		1,157
Deferred charges related to income taxes	557		550
Prepaid pension costs	608		563
Deferred under recovered fuel clause revenues	494		410
Regulatory assets – asset retirement obligations, deferred	3,781		3,688
Other regulatory assets, deferred	2,067		1,964
Other deferred charges and assets	506		491
Total deferred charges and other assets	9,133		8,823
Total Assets	$	49,206	$	48,461

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	275	$	675
Notes payable	860		—
Accounts payable —
Affiliated	548		757
Other	873		702
Customer deposits	257		259
Accrued taxes	196		335
Accrued interest	93		136
Accrued compensation	124		232
Operating lease obligations	156		156
Asset retirement obligations	314		317
Other regulatory liabilities	336		280
Other current liabilities	292		254
Total current liabilities	4,324		4,103
Long-term Debt	13,088		13,109
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,155		3,019
Deferred credits related to income taxes	2,303		2,321
Accumulated deferred ITCs	326		328
Employee benefit obligations	390		402
Operating lease obligations, deferred	989		999
Asset retirement obligations, deferred	6,526		6,507
Other deferred credits and liabilities	456		439
Total deferred credits and other liabilities	14,145		14,015
Total Liabilities	31,557		31,227
Common Stockholder's Equity (See accompanying statements)	17,649		17,234
Total Liabilities and Stockholder's Equity	$	49,206	$	48,461

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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GEORGIA POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED)

	Number of Common Shares Issued	Common Stock		Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total
	(in millions)
Balance at December 31, 2020	9	$	398	$	12,361	$	3,789	$	(47)	$	16,501
Net income	—	—		—		351		—		351
Capital contributions from parent company	—	—		332		—		—		332
Other comprehensive income	—	—		—		—		2		2
Cash dividends on common stock	—	—		—		(412)		—		(412)
Balance at March 31, 2021	9	$	398	$	12,693	$	3,728	$	(45)	$	16,774
Balance at December 31, 2021	9	$	398	$	14,153	$	2,724	$	(41)	$	17,234
Net income	—	—		—		385		—		385
Capital contributions from parent company	—	—		443		—		—		443
Other comprehensive income	—	—		—		—		10		10
Cash dividends on common stock	—	—		—		(423)		—		(423)
Balance at March 31, 2022	9	$	398	$	14,596	$	2,686	$	(31)	$	17,649

The accompanying notes as they relate to Georgia Power are an integral part of these condensed financial statements.

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MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF INCOME AND COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Retail revenues	$	217	$	204
Wholesale revenues, non-affiliates	68		63
Wholesale revenues, affiliates	42		33
Other revenues	8		7
Total operating revenues	335		307
Operating Expenses:
Fuel and purchased power	132		106
Other operations and maintenance	76		68
Depreciation and amortization	45		47
Taxes other than income taxes	29		31
Total operating expenses	282		252
Operating Income	53		55
Other Income and (Expense):
Interest expense, net of amounts capitalized	(13)		(14)
Other income (expense), net	10		8
Total other income and (expense)	(3)		(6)
Earnings Before Income Taxes	50		49
Income taxes	8		4
Net Income and Comprehensive Income	$	42	$	45

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

26

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	42	$	45
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	55		53
Deferred income taxes	(5)		4
Other, net	17		(14)
Changes in certain current assets and liabilities —
-Receivables	(7)		7
-Retail fuel cost under recovery	(11)		—
-Other current assets	(11)		1
-Accounts payable	(9)		(30)
-Accrued taxes	(63)		(75)
-Accrued compensation	(18)		(16)
-Other current liabilities	(6)		(13)
Net cash used for operating activities	(16)		(38)
Investing Activities:
Property additions	(45)		(45)
Construction payables	(8)		(8)
Payments pursuant to LTSAs	(8)		(7)
Other investing activities	(7)		(7)
Net cash used for investing activities	(68)		(67)
Financing Activities:
Increase in notes payable, net	25		29
Capital contributions from parent company	50		100
Payment of common stock dividends	(43)		(39)
Net cash provided from financing activities	32		90
Net Change in Cash, Cash Equivalents, and Restricted Cash	(52)		(15)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	61		39
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	9	$	24
Supplemental Cash Flow Information:
Cash paid during the period for —
Interest	$	22	$	16
Noncash transactions — Accrued property additions at end of period	17		26

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

27

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	9	$	61
Receivables —
Customer accounts, net	65		37
Unbilled revenues	36		34
Affiliated	17		29
Other accounts and notes	30		28
Fossil fuel stock	30		28
Materials and supplies	72		70
Assets from risk management activities	94		28
Other regulatory assets	61		54
Other current assets	10		13
Total current assets	424		382
Property, Plant, and Equipment:
In service	5,149		5,106
Less: Accumulated provision for depreciation	1,626		1,591
Plant in service, net of depreciation	3,523		3,515
Construction work in progress	111		127
Total property, plant, and equipment	3,634		3,642
Other Property and Investments	177		179
Deferred Charges and Other Assets:
Deferred charges related to income taxes	30		31
Prepaid pension costs	85		79
Regulatory assets – asset retirement obligations	235		232
Other regulatory assets, deferred	298		317
Accumulated deferred income taxes	115		118
Other deferred charges and assets	127		100
Total deferred charges and other assets	890		877
Total Assets	$	5,125	$	5,080

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

28

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	1	$	1
Notes payable	25		—
Accounts payable —
Affiliated	58		81
Other	53		47
Accrued taxes	56		120
Accrued compensation	20		36
Asset retirement obligations	28		30
Other regulatory liabilities	120		59
Other current liabilities	55		65
Total current liabilities	416		439
Long-term Debt	1,510		1,510
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	462		464
Deferred credits related to income taxes	269		269
Employee benefit obligations	88		88
Asset retirement obligations, deferred	161		160
Other cost of removal obligations	194		195
Other regulatory liabilities, deferred	84		64
Other deferred credits and liabilities	24		24
Total deferred credits and other liabilities	1,282		1,264
Total Liabilities	3,208		3,213
Common Stockholder's Equity (See accompanying statements)	1,917		1,867
Total Liabilities and Stockholder's Equity	$	5,125	$	5,080

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

29

    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

CONDENSED STATEMENTS OF COMMON STOCKHOLDER'S EQUITY (UNAUDITED)

	Number of Common Shares Issued	Common Stock		Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Total
	(in millions)
Balance at December 31, 2020	1	$	38	$	4,460	$	(2,754)	$	(2)	$	1,742
Net income	—	—		—		45		—		45
Capital contributions from parent company	—	—		100		—		—		100
Cash dividends on common stock	—	—		—		(39)		—		(39)
Balance at March 31, 2021	1	$	38	$	4,560	$	(2,748)	$	(2)	$	1,848
Balance at December 31, 2021	1	$	38	$	4,582	$	(2,753)	$	—	$	1,867
Net income	—	—		—		42		—		42
Capital contributions from parent company	—	—		51		—		—		51
Cash dividends on common stock	—	—		—		(43)		—		(43)
Balance at March 31, 2022	1	$	38	$	4,633	$	(2,754)	$	—	$	1,917

The accompanying notes as they relate to Mississippi Power are an integral part of these condensed financial statements.

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    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Wholesale revenues, non-affiliates	$	426	$	355
Wholesale revenues, affiliates	105		81
Other revenues	8		4
Total operating revenues	539		440
Operating Expenses:
Fuel	232		141
Purchased power	21		20
Other operations and maintenance	105		101
Depreciation and amortization	120		119
Taxes other than income taxes	13		12
Gain on dispositions, net	(2)		(39)
Total operating expenses	489		354
Operating Income	50		86
Other Income and (Expense):
Interest expense, net of amounts capitalized	(37)		(38)
Other income (expense), net	2		7
Total other income and (expense)	(35)		(31)
Earnings Before Income Taxes	15		55
Income taxes (benefit)	(12)		(10)
Net Income	27		65
Net loss attributable to noncontrolling interests	(45)		(32)
Net Income Attributable to Southern Power	$	72	$	97

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Net Income	$	27	$	65
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $(6) and $(11), respectively	(17)		(33)
Reclassification adjustment for amounts included in net income,    net of tax of $7 and $15, respectively	22		48
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income,    net of tax of $— and $—, respectively	—		1
Total other comprehensive income	5		16
Comprehensive Income	32		81
Comprehensive loss attributable to noncontrolling interests	(45)		(32)
Comprehensive Income Attributable to Southern Power	$	77	$	113

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	27	$	65
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	126		125
Deferred income taxes	12		(8)
Amortization of investment tax credits	(15)		(15)
Gain on dispositions, net	(2)		(39)
Other, net	(3)		(4)
Changes in certain current assets and liabilities —
-Receivables	11		23
-Prepaid income taxes	(8)		16
-Other current assets	—		3
-Accounts payable	(21)		19
-Accrued taxes	7		5
-Other current liabilities	(17)		(3)
Net cash provided from operating activities	117		187
Investing Activities:
Business acquisitions, net of cash acquired	—		(345)
Property additions	(19)		(147)
Proceeds from dispositions	29		17
Change in construction payables	(31)		(7)
Payments pursuant to LTSAs	(15)		(27)
Other investing activities	(1)		5
Net cash used for investing activities	(37)		(504)
Financing Activities:
Increase (decrease) in notes payable, net	(3)		140
Proceeds — Senior notes	—		400
Return of capital to parent company	—		(271)
Capital contributions from noncontrolling interests	73		313
Distributions to noncontrolling interests	(97)		(46)
Payment of common stock dividends	(49)		(51)
Other financing activities	—		(7)
Net cash provided from (used for) financing activities	(76)		478
Net Change in Cash, Cash Equivalents, and Restricted Cash	4		161
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	135		182
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	139	$	343
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $— and $1 capitalized for 2022 and 2021, respectively)	$	29	$	26
Income taxes, net	(8)		(2)
Noncash transactions —
Contributions from noncontrolling interests	—		89
Contributions of wind turbine equipment	—		82
Accrued property additions at end of period	46		60
Right-of-use assets obtained under operating leases	—		65
Reassessment of right-of-use assets under operating leases	40		—

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	130	$	107
Receivables —
Customer accounts, net	160		139
Affiliated	26		51
Other	21		29
Materials and supplies	108		106
Prepaid income taxes	468		27
Other current assets	49		46
Total current assets	962		505
Property, Plant, and Equipment:
In service	14,594		14,585
Less: Accumulated provision for depreciation	3,341		3,241
Plant in service, net of depreciation	11,253		11,344
Construction work in progress	49		45
Total property, plant, and equipment	11,302		11,389
Other Property and Investments:
Intangible assets, net of amortization of $114 and $109, respectively	278		282
Equity investments in unconsolidated subsidiaries	56		86
Net investment in sales-type leases	159		161
Total other property and investments	493		529
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	517		479
Prepaid LTSAs	219		210
Income taxes receivable, non-current	23		20
Other deferred charges and assets	250		258
Total deferred charges and other assets	1,009		967
Total Assets	$	13,766	$	13,390

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

33

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholders' Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	666	$	679
Notes payable	208		211
Accounts payable —
Affiliated	82		92
Other	67		85
Accrued taxes	21		14
Accrued interest	32		32
Other current liabilities	121		140
Total current liabilities	1,197		1,253
Long-term Debt	2,999		3,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	661		215
Accumulated deferred ITCs	1,600		1,614
Operating lease obligations	535		497
Other deferred credits and liabilities	218		204
Total deferred credits and other liabilities	3,014		2,530
Total Liabilities	7,210		6,792
Total Stockholders' Equity (See accompanying statements)	6,556		6,598
Total Liabilities and Stockholders' Equity	$	13,766	$	13,390

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (UNAUDITED)

	Paid-In Capital		Retained Earnings		Accumulated Other Comprehensive Income (Loss)		Total Common Stockholders' Equity		Noncontrolling Interests		Total
	(in millions)
Balance at December 31, 2020	$	914	$	1,522	$	(67)	$	2,369	$	4,262	$	6,631
Net income (loss)	—		97		—		97		(32)		65
Return of capital to parent company	(271)		—		—		(271)		—		(271)
Other comprehensive income	—		—		16		16		—		16
Cash dividends on common stock	—		(51)		—		(51)		—		(51)
Capital contributions from    noncontrolling interests	—		—		—		—		403		403
Distributions to noncontrolling interests	—		—		—		—		(46)		(46)
Other	(2)		1		(1)		(2)		(1)		(3)
Balance at March 31, 2021	$	641	$	1,569	$	(52)	$	2,158	$	4,586	$	6,744

Balance at December 31, 2021	$	638	$	1,585	$	(27)	$	2,196	$	4,402	$	6,598
Net income (loss)	—		72		—		72		(45)		27
Other comprehensive income	—		—		5		5		—		5
Cash dividends on common stock	—		(49)		—		(49)		—		(49)
Capital contributions from    noncontrolling interests	—		—		—		—		73		73
Distributions to noncontrolling interests	—		—		—		—		(98)		(98)
Balance at March 31, 2022	$	638	$	1,608	$	(22)	$	2,224	$	4,332	$	6,556

The accompanying notes as they relate to Southern Power are an integral part of these condensed consolidated financial statements.

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Revenues:
Natural gas revenues (includes revenue taxes of $71 and $54, respectively)	$	2,058	$	1,692
Alternative revenue programs	—		2
Total operating revenues	2,058		1,694
Operating Expenses:
Cost of natural gas	1,095		583
Other operations and maintenance	305		299
Depreciation and amortization	137		130
Taxes other than income taxes	100		81
Total operating expenses	1,637		1,093
Operating Income	421		601
Other Income and (Expense):
Earnings from equity method investments	40		41
Interest expense, net of amounts capitalized	(61)		(60)
Other income (expense), net	16		(63)
Total other income and (expense)	(5)		(82)
Earnings Before Income Taxes	416		519
Income taxes	97		121
Net Income	$	319	$	398

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Net Income	$	319	$	398
Other comprehensive income:
Qualifying hedges:
Changes in fair value, net of tax of $10 and $—, respectively	26		1
Reclassification adjustment for amounts included in net income,    net of tax of $(2) and $1, respectively	(6)		3
Total other comprehensive income	20		4
Comprehensive Income	$	339	$	402

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

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    Table of Contents                                Index to Financial Statements

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (UNAUDITED)

	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Operating Activities:
Net income	$	319	$	398
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	137		130
Deferred income taxes	5		160
Mark-to-market adjustments	(38)		64
Natural gas cost under recovery – long-term	162		(185)
Other, net	41		5
Changes in certain current assets and liabilities —
-Receivables	(115)		74
-Natural gas for sale, net of temporary LIFO liquidation	450		456
-Prepaid income taxes	34		(51)
-Natural gas cost under recovery	(40)		(487)
-Other current assets	39		17
-Accounts payable	(23)		(7)
-Accrued taxes	54		10
-Other current liabilities	(1)		(34)
Net cash provided from operating activities	1,024		550
Investing Activities:
Property additions	(247)		(251)
Cost of removal, net of salvage	(20)		(16)
Change in construction payables, net	(5)		(47)
Other investing activities	1		6
Net cash used for investing activities	(271)		(308)
Financing Activities:
Decrease in notes payable, net	(577)		(127)
Proceeds — Short-term borrowings	—		300
Redemptions —
Short-term borrowings	(100)		—
Medium-term notes	—		(30)
Capital contributions from parent company	39		39
Payment of common stock dividends	(130)		(132)
Net cash provided from (used for) financing activities	(768)		50
Net Change in Cash, Cash Equivalents, and Restricted Cash	(15)		292
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	48		19
Cash, Cash Equivalents, and Restricted Cash at End of Period	$	33	$	311
Supplemental Cash Flow Information:
Cash paid (received) during the period for —
Interest (net of $2 capitalized for both 2022 and 2021)	$	55	$	52
Income taxes, net	—		(1)
Noncash transactions — Accrued property additions at end of period	107		95

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

37

    Table of Contents                                Index to Financial Statements

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Assets	At March 31, 2022		At December 31, 2021
	(in millions)
Current Assets:
Cash and cash equivalents	$	31	$	45
Receivables —
Customer accounts	603		462
Unbilled revenues	245		278
Other accounts and notes	52		49
Accumulated provision for uncollectible accounts	(51)		(39)
Natural gas for sale	121		362
Prepaid expenses	88		114
Assets from risk management activities, net of collateral	53		33
Natural gas cost under recovery	306		266
Other regulatory assets	104		136
Other current assets	47		49
Total current assets	1,599		1,755
Property, Plant, and Equipment:
In service	19,035		18,880
Less: Accumulated depreciation	5,159		5,067
Plant in service, net of depreciation	13,876		13,813
Construction work in progress	768		684
Total property, plant, and equipment	14,644		14,497
Other Property and Investments:
Goodwill	5,015		5,015
Equity investments in unconsolidated subsidiaries	1,178		1,173
Other intangible assets, net of amortization of $148 and $145, respectively	34		37
Miscellaneous property and investments	19		19
Total other property and investments	6,246		6,244
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	67		70
Prepaid pension costs	183		175
Other regulatory assets, deferred	508		689
Other deferred charges and assets	130		130
Total deferred charges and other assets	888		1,064
Total Assets	$	23,377	$	23,560

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

38

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SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED BALANCE SHEETS (UNAUDITED)

Liabilities and Stockholder's Equity	At March 31, 2022		At December 31, 2021
	(in millions)
Current Liabilities:
Securities due within one year	$	46	$	47
Notes payable	532		1,209
Accounts payable —
Affiliated	40		58
Other	349		361
Customer deposits	72		95
Accrued taxes	191		124
Accrued interest	68		59
Accrued compensation	66		110
Temporary LIFO liquidation	209		—
Other regulatory liabilities	72		8
Other current liabilities	140		155
Total current liabilities	1,785		2,226
Long-term Debt	6,814		6,855
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,568		1,555
Deferred credits related to income taxes	808		816
Employee benefit obligations	168		176
Operating lease obligations	58		59
Other cost of removal obligations	1,692		1,683
Accrued environmental remediation	189		197
Other deferred credits and liabilities	120		77
Total deferred credits and other liabilities	4,603		4,563
Total Liabilities	13,202		13,644
Common Stockholder's Equity (See accompanying statements)	10,175		9,916
Total Liabilities and Stockholder's Equity	$	23,377	$	23,560

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

39

    Table of Contents                                Index to Financial Statements

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

CONDENSED CONSOLIDATED STATEMENTS OF STOCKHOLDER'S EQUITY (UNAUDITED)

	Paid-In Capital		Retained Earnings (Accumulated Deficit)		Accumulated Other Comprehensive Income (Loss)		Total
	(in millions)
Balance at December 31, 2020	$	9,930	$	(141)	$	(22)	$	9,767
Net income	—		398		—		398
Capital contributions from parent company	57		—		—		57
Other comprehensive income	—		—		4		4
Cash dividends on common stock	—		(132)		—		(132)
Balance at March 31, 2021	9,987		125		(18)		10,094
Balance at December 31, 2021	$	10,024	$	(132)	$	24	$	9,916
Net income	—		319		—		319
Capital contributions from parent company	50		—		—		50
Other comprehensive income	—		—		20		20
Cash dividends on common stock	—		(130)		—		(130)
Balance at March 31, 2022	$	10,074	$	57	$	44	$	10,175

The accompanying notes as they relate to Southern Company Gas are an integral part of these condensed consolidated financial statements.

40

    Table of Contents                                Index to Financial Statements

NOTES TO THE CONDENSED FINANCIAL STATEMENTS

FOR

THE SOUTHERN COMPANY AND SUBSIDIARY COMPANIES

ALABAMA POWER COMPANY

GEORGIA POWER COMPANY

MISSISSIPPI POWER COMPANY

SOUTHERN POWER COMPANY AND SUBSIDIARY COMPANIES

SOUTHERN COMPANY GAS AND SUBSIDIARY COMPANIES

(UNAUDITED)

INDEX TO THE NOTES TO THE CONDENSED FINANCIAL STATEMENTS

Note		Page
A	Introduction	42
B	Regulatory Matters	45
C	Contingencies	52
D	Revenue from Contracts with Customers and Lease Income	55
E	Consolidated Entities and Equity Method Investments	58
F	Financing	60
G	Income Taxes	61
H	Retirement Benefits	62
I	Fair Value Measurements	64
J	Derivatives	69
K	Acquisitions and Dispositions	83
L	Segment and Related Information	83

INDEX TO APPLICABLE NOTES TO FINANCIAL STATEMENTS BY REGISTRANT

The following unaudited notes to the condensed financial statements are a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants. The list below indicates the Registrants to which each footnote applies.

Registrant	Applicable Notes
Southern Company	A, B, C, D, E, F, G, H, I, J, K, L
Alabama Power	A, B, C, D, F, G, H, I, J
Georgia Power	A, B, C, D, F, G, H, I, J
Mississippi Power	A, B, C, D, F, G, H, I, J
Southern Power	A, C, D, E, F, G, H, I, J, K
Southern Company Gas	A, B, C, D, E, F, G, H, I, J, L

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(UNAUDITED)

(A) INTRODUCTION

The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2021 have been derived from the audited financial statements of each Registrant. In the opinion of each Registrant's management, the information regarding such Registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended March 31, 2022 and 2021. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each Registrant believes that the disclosures regarding such Registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy and other factors, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year.

Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant.

Goodwill and Other Intangible Assets

Goodwill at March 31, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

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Other intangible assets were as follows:

	At March 31, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(152)	$	60	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(114)		276		390		(109)		281
Other	11		(10)		1		11		(10)		1
Total other intangible assets subject to amortization	$	677	$	(317)	$	360	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	752	$	(317)	$	435	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(114)	$	276	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(132)	$	24	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(148)	$	34	$	182	$	(145)	$	37

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Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2022
	(in millions)
Southern Company(a)	$	10
Southern Power(b)	5
Southern Company Gas	3

(a)Includes $5 million recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,662	$	1,798	$	130	$	107	$	31	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,673	$	1,829	$	139	$	135	$	33	$	48

(a)For Southern Power, restricted cash reflects $9 million and $10 million at March 31, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects restricted cash held as collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated.

Southern Company Gas recorded no material adjustments to natural gas inventories for either period presented. Nicor Gas' inventory decrement at March 31, 2022 is expected to be restored prior to year end.

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Depreciation and Amortization

See Note 5 to the financial statements under "Depreciation and Amortization – Southern Power" in Item 8 of the Form 10-K for additional information.

Effective January 1, 2022, Southern Power revised the depreciable lives of its wind generating facilities from up to 30 years to up to 35 years. This revision resulted in an immaterial decrease in depreciation for the three months ended March 31, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.

(B) REGULATORY MATTERS

See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at March 31, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	12	$	16
Rate CNP PPA	Other regulatory assets, deferred	84		84
Retail Energy Cost Recovery(*)	Other regulatory assets, deferred	46		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	494	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	16	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	33		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	306	$	266
	Other regulatory assets, deferred	44		207
	Other regulatory liabilities, current	13		—

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Alabama Power

Certificate of Convenience and Necessity

On March 25, 2022, the FERC approved Alabama Power's acquisition of the Calhoun Generating Station, which is expected to be completed by September 30, 2022. The completion of the acquisition remains subject to approval by the Alabama PSC. The ultimate outcome of this matter cannot be determined at this time.

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Georgia Power

Rate Plan

In 2020, the Georgia PSC denied a motion for reconsideration filed by the Sierra Club regarding the Georgia PSC's decision in the 2019 ARP allowing Georgia Power to recover compliance costs for CCR AROs. The Superior Court of Fulton County subsequently affirmed the Georgia PSC's decision and, in October 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County's order. In December 2021, the Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court. The ultimate outcome of this matter cannot be determined at this time. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information regarding Georgia Power's AROs.

Integrated Resource Plan

In light of the ongoing supply chain challenges in the solar industry, Georgia Power amended the 970 MWs of utility-scale PPAs authorized in its 2019 Integrated Resource Plan to extend by one year the in-service dates for solar generation resources to the end of 2024.

Nuclear Construction

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.

In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days' written notice.

In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs, and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners, Vogtle Owner insolvency, and certain other events.

See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events.

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Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,294
Construction contingency estimate	107
Total project capital cost forecast(a)(b)	10,401
Net investment at March 31, 2022(b)	(8,715)
Remaining estimate to complete	$	1,686

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $440 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $377 million, of which $221 million had been accrued through March 31, 2022.

(b)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.

Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion, of which $3.0 billion had been incurred through March 31, 2022.

As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system turnover activities, which are reflected in the site work plans.

Since March 2020, the number of active COVID-19 cases at the site has fluctuated consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed approximately three to four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of March 31, 2022, Georgia Power's proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions and impacts on construction productivity is estimated to be between $160 million and $200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.

Fuel load for Unit 3 is projected during the third quarter or the fourth quarter 2022 with an in-service date projected during the fourth quarter 2022 or the first quarter 2023. Unit 3's projected schedule primarily depends on improvements in overall construction productivity and production levels, the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the third quarter or the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on overall construction productivity and production levels improving as well as appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates.

During the first quarter 2022, established construction contingency totaling $43 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, and support resources for Units 3 and 4.

As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential future challenges include construction productivity, completion of construction remediation work,

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(UNAUDITED)

completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests. As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include the pace and quality of electrical installation; availability of craft and supervisory resources, including the temporary diversion of such resources to support Unit 3 construction efforts; the pace of work package closures and system turnovers; and the timeframe and duration of hot functional and other testing. As construction, including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical, mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and potential future challenges described above may change the projected schedule and estimated cost.

There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and state level and additional challenges may arise. In addition, certain license amendment requests have been filed and approved or are pending before the NRC. Processes are in place that are designed to ensure compliance with the requirements specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work described above, Southern Nuclear reviewed the project's construction quality programs and, where needed, is implementing improvement plans consistent with these processes. On March 25, 2022, the NRC completed its follow-up inspection related to the November 2021 final significance report on its special inspection to review the root cause of this additional construction remediation work and the corresponding corrective action plans. The NRC closed the two white findings identified in November 2021 and returned Vogtle Unit 3 to the NRC's baseline inspection program.

Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.

The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described below, is estimated to result in additional base capital costs for Georgia Power of up to $60 million per month for Unit 3 and $40 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required to be charged to income and such charges could be material.

Joint Owner Contracts

In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern

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Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct.

Amendments to the Vogtle Joint Ownership Agreements

In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).

Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which formed the basis of Georgia Power's forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $2.1 billion.

For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and 4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $100,000 or more.

In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for

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(UNAUDITED)

recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. Effective February 25, 2022, all of the Vogtle Owners had voted to continue construction.

Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact those provisions. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and the current project capital cost forecast exceeds the cost-sharing provision threshold, but not the tender provision threshold. The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded a pre-tax charge to income in the fourth quarter 2021 of approximately $440 million ($328 million after tax) associated with these cost-sharing and tender provisions, which is included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $460 million associated with these provisions based on the current project capital cost forecast. Georgia Power's incremental charges associated with these provisions, which relate to the other Vogtle Owners' share of costs, will not be recovered from retail customers. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 180 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the other Vogtle Owners exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.

The ultimate outcome of these matters cannot be determined at this time.

Regulatory Matters

In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At March 31, 2022, Georgia Power had recovered approximately $2.8 billion of financing costs. Financing costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.

Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.

In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January 11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11,

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(UNAUDITED)

2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and prudent and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable Georgia Power's revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively; (vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $270 million in 2021 and are estimated to have negative earnings impacts of approximately $300 million and $265 million in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions upon which Georgia Power's seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the decision to continue construction.

In the August 2021 order approving the twenty-fourth VCM report, the Georgia PSC approved a stipulation addressing the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the $7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above $7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.

The Georgia PSC has approved 25 VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $7.9 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds), of which the Georgia PSC has verified and approved $7.3 billion as described above. Georgia Power filed its twenty-sixth VCM report with the Georgia PSC on February 17, 2022, reflecting $584 million of additional construction capital costs incurred through December 31, 2021 and the total capital cost forecast described above.

The ultimate outcome of these matters cannot be determined at this time.

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Mississippi Power

Performance Evaluation Plan

On March 15, 2022, Mississippi Power submitted its annual retail PEP filing for 2022 to the Mississippi PSC, which requested a 1.9%, or approximately $18 million, annual increase in revenues, primarily due to increases in investment, operations and maintenance expenses, and depreciation and amortization. In accordance with the PEP rate schedule, the rate increase became effective with the first billing cycle of April 2022, subject to refund. The related proceedings are expected to conclude in summer 2022; however, the ultimate outcome of this matter cannot be determined at this time.

Ad Valorem Tax Adjustment

On April 13, 2022, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2022, which requested a $5 million annual increase in revenues. The ultimate outcome of this matter cannot be determined at this time.

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2022 were as follows:

Utility	Program	Three Months Ended March 31, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	51
Virginia Natural Gas	Steps to Advance Virginia's Energy	14
Atlanta Gas Light	System Reinforcement Rider	14
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	80

(C) CONTINGENCIES

See Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.

General Litigation Matters

The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements.

The Registrants believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.

Southern Company

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of

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Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that names as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. In August 2019, the court granted a motion filed by the plaintiff in July 2019 to substitute a new named plaintiff, Martin J. Kobuck, in place of Helen E. Piper Survivor's Trust.

The plaintiffs in each of these cases seek to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiffs also seek certain changes to Southern Company's corporate governance and internal processes. On January 21, 2022, the plaintiffs in the federal court action filed a motion for preliminary approval of settlement, together with an executed stipulation of settlement, which applies to both actions. On March 11, 2022, the U.S. District Court for the Northern District of Georgia entered an order preliminarily approving the settlement. The proposed settlement consists of an aggregate payment by Southern Company's insurers of approximately $4.5 million for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. The terms of the proposed settlement and the corporate governance reforms remain subject to final approval by the court.

Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last several years. In 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented the municipal franchise fee schedule. In March 2021, the Superior Court of Fulton County granted class certification and Georgia Power's motion for summary judgment and the plaintiffs filed a notice of appeal. In April 2021, Georgia Power filed a notice of cross appeal on the issue of class certification. In December 2021, the Georgia Court of Appeals affirmed the Superior Court's ruling that granted summary judgment to Georgia Power and dismissed Georgia Power's cross appeal on the issue of class certification as moot. Also in December 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any municipalities.

In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. In October 2021, three additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the three cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. On February 7, 2022, four additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the four cases pending in the Superior Court of Monroe

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County, Georgia to the U.S. District Court for the Middle District of Georgia. The amount of any possible losses from these matters cannot be estimated at this time.

Mississippi Power

In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. The appellate court remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. The appellate court's decision is not final until the opportunity for rehearing en banc is resolved. An adverse outcome in this proceeding could have a material impact on Mississippi Power's financial statements.

Environmental Remediation

The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities in Illinois and Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental remediation costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable state regulatory agencies.

Georgia Power's environmental remediation liability was $16 million and $17 million at March 31, 2022 and December 31, 2021, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $249 million at both March 31, 2022 and December 31, 2021 based on the estimated cost of environmental investigation and remediation associated with known former manufactured gas plant operating sites.

The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants.

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(D) REVENUE FROM CONTRACTS WITH CUSTOMERS AND LEASE INCOME

Revenue from Contracts with Customers

The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.

The following table disaggregates revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(a)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

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	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Operating revenues
Retail electric revenues
Residential	$	1,468	$	628	$	776	$	64	$	—	$	—
Commercial	1,117		372		686		59		—		—
Industrial	668		320		284		64		—		—
Other	24		5		17		2		—		—
Total retail electric revenues	3,277		1,325		1,763		189		—		—
Natural gas distribution revenues
Residential	614		—		—		—		—		614
Commercial	170		—		—		—		—		170
Transportation	288		—		—		—		—		288
Industrial	16		—		—		—		—		16
Other	97		—		—		—		—		97
Total natural gas distribution revenues	1,185		—		—		—		—		1,185
Wholesale electric revenues
PPA energy revenues	212		43		13		4		156		—
PPA capacity revenues	119		29		13		3		75		—
Non-PPA revenues	67		32		9		88		61		—
Total wholesale electric revenues	398		104		35		95		292		—
Other natural gas revenues
Wholesale gas services	1,590		—		—		—		—		1,590
Gas marketing services	194		—		—		—		—		194
Other natural gas revenues	7		—		—		—		—		7
Total natural gas revenues	1,791		—		—		—		—		1,791
Other revenues	249		46		113		8		4		—
Total revenue from contracts with customers	6,900		1,475		1,911		292		296		2,976
Other revenue sources(a)	1,306		84		59		15		144		1,014
Other adjustments(b)	(2,296)		—		—		—		—		(2,296)
Total operating revenues	$	5,910	$	1,559	$	1,970	$	307	$	440	$	1,694

(a)Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas, and cost recovery mechanisms and revenues that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

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Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at March 31, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2022	$	2,571	$	616	$	695	$	85	$	128	$	865
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At March 31, 2022	$	81	$	2	$	31	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At March 31, 2022	$	72	$	3	$	13	$	2	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

At March 31, 2022 and December 31, 2021, Georgia Power had contract assets primarily related to retail customer fixed bill programs, where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over a one-year contract term, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company's unregulated distributed generation business had $47 million and $50 million of contract assets and $54 million and $39 million of contract liabilities at March 31, 2022 and December 31, 2021, respectively, for outstanding performance obligations.

Revenues recognized in the three months ended March 31, 2022, which were included in contract liabilities at December 31, 2021, were immaterial for all Registrants.

Remaining Performance Obligations

The Subsidiary Registrants have long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to PPAs whereby electricity and generation capacity are provided to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at March 31, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	529	$	459	$	351	$	321	$	307	$	2,345
Alabama Power	24		24		7		5		—		—
Georgia Power	55		55		26		22		11		21
Southern Power	252		294		310		294		299		2,339

Revenue expected to be recognized for performance obligations remaining at March 31, 2022 was immaterial for Mississippi Power and Southern Company Gas.

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Lease Income

Lease income for the three months ended March 31, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9
For the Three Months Ended March 31, 2021
Lease income - interest income on sales-type leases	$	3	$	—	$	—	$	3	$	—	$	—
Lease income - operating leases	55		21		10		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	142	$	21	$	10	$	3	$	111	$	9

Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income for Alabama Power and Southern Power is included in wholesale revenues.

(E) CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTS

See Note 7 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Power

Variable Interest Entities

Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the obligation to absorb expected losses of these VIEs to the extent of its equity interests.

SP Solar and SP Wind

At March 31, 2022 and December 31, 2021, SP Solar had total assets of $6.0 billion and $6.1 billion, respectively, total liabilities of $407 million and $408 million, respectively, and noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.

At March 31, 2022 and December 31, 2021, SP Wind had total assets of $2.3 billion, total liabilities of $180 million and $130 million, respectively, and noncontrolling interests of $41 million. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three financial investors in accordance with the limited liability agreement.

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(UNAUDITED)

Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt.

Other Variable Interest Entities

Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights.

At March 31, 2022 and December 31, 2021, the other VIEs had total assets of $1.8 billion and $1.9 billion, respectively, total liabilities of $248 million and $263 million, respectively, and noncontrolling interests of $876 million and $886 million, respectively. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.

Equity Method Investments

At March 31, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy storage projects totaling $56 million and $86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the first quarter 2022, Southern Power sold an equity method investment in a wind project and received proceeds of $31 million. The gain associated with the transaction was immaterial.

Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2022 and December 31, 2021 and related earnings from those investments for the three months ended March 31, 2022 and 2021 were as follows:

Investment Balance	March 31, 2022		December 31, 2021
	(in millions)
SNG	$	1,138	$	1,129
Other(*)	40		44
Total	$	1,178	$	1,173

(*)Balance at March 31, 2022 reflects a $4 million distribution from PennEast Pipeline.

	Three Months Ended March 31,
Earnings from Equity Method Investments	2022		2021
	(in millions)
SNG	$	39	$	38
Other(*)	1		3
Total	$	40	$	41

(*)Earnings primarily result from AFUDC equity recorded by the project entity.

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(UNAUDITED)

(F) FINANCING

Bank Credit Arrangements

See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.

At March 31, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2022		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		255		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,747		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,574	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $19 million, respectively, was unused at March 31, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of the arrangement expiring in 2026 and all $250 million of the arrangement expiring in 2022. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

As reflected in the table above, in March 2022, Mississippi Power amended and restated its $125 million revolving credit arrangement, which among other things, extended the maturity date from 2023 to 2025 and allows for borrowing based on term SOFR.

Subject to applicable market conditions, Southern Company and its subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern Company and its subsidiaries may extend the maturity dates and/or increase or decrease the lending commitments thereunder.

These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration or, in the case of Southern Power, cross-default provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness of the individual company. Such cross-default provisions to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a specified threshold. Such cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2022, the Registrants, Nicor Gas, and SEGCO were in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings.

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(UNAUDITED)

A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at March 31, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at March 31, 2022, Georgia Power had approximately $330 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

Earnings per Share

For Southern Company, the only differences in computing basic and diluted earnings per share are attributable to awards outstanding under stock-based compensation plans and the equity units issued in 2019. Earnings per share dilution resulting from stock-based compensation plans and the equity units issuance is determined using the treasury stock method. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K for information on the equity units and Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31,
	2022	2021
	(in millions)
As reported shares	1,063	1,060
Effect of stock-based compensation	6	6
Diluted shares	1,069	1,066

An immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive for the three months ended March 31, 2022 and 2021.

(G) INCOME TAXES

See Note 10 to the financial statements in Item 8 of the Form 10-K for additional tax information.

Current and Deferred Income Taxes

Tax Credit and Net Operating Loss Carryforwards

The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, an increase in Georgia Power's ownership interest percentage in Plant Vogtle Units 3 and 4, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership agreements, changes in taxable income projections, and potential income tax rate changes. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.

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Effective Tax Rate

Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power.

Details of significant changes in the effective tax rate for the applicable Registrants are provided herein.

Mississippi Power

Mississippi Power's effective tax rate was 16.4% for the three months ended March 31, 2022 compared to 8.4% for the corresponding period in 2021. The effective tax rate increase was primarily due to a decrease in the flowback of excess deferred income taxes beginning in April 2021.

Southern Power

Southern Power's effective tax benefit rate was (80.0)% for the three months ended March 31, 2022 compared to (17.3)% for the corresponding period in 2021. The effective tax rate decrease was primarily due to lower pre-tax earnings and higher wind PTCs in 2022, partially offset by changes in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in February 2021.

(H) RETIREMENT BENEFITS

The Southern Company system has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.

During the first quarter 2022, the qualified pension plan achieved the predetermined funding threshold whereby the asset allocation was adjusted to invest a larger portion of the portfolio in fixed rate debt securities.

See Note 11 to the financial statements in Item 8 of the Form 10-K for additional information.

On each Registrant's condensed statements of income, the service cost component of net periodic benefit costs is included in other operations and maintenance expenses and all other components of net periodic benefit costs are included in other income (expense), net. Components of the net periodic benefit costs for the three months ended March 31, 2022 and 2021 are presented in the following tables.

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(UNAUDITED)

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

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(UNAUDITED)

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Pension Plans
Service cost	$	109	$	26	$	28	$	4	$	2	$	9
Interest cost	87		20		26		4		1		6
Expected return on plan assets	(298)		(72)		(94)		(14)		(3)		(21)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	78		21		25		4		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(15)	$	(2)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	8		2		3		—		—		1
Expected return on plan assets	(19)		(7)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net (gain)/loss	1		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	—

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(UNAUDITED)

(I) FAIR VALUE MEASUREMENTS

At March 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Southern Company
Assets:
Energy-related derivatives(a)	$	74	$	473	$	—	$	—	$	547
Interest rate derivatives	—		17		—		—		17
Investments in trusts:(b)(c)
Domestic equity	754		202		—		—		956
Foreign equity	143		167		—		—		310
U.S. Treasury and government agency securities	—		290		—		—		290
Municipal bonds	—		53		—		—		53
Pooled funds – fixed income	—		10		—		—		10
Corporate bonds	1		490		—		—		491
Mortgage and asset backed securities	—		88		—		—		88
Private equity	—		—		—		156		156
Cash and cash equivalents	3		—		—		—		3
Other	42		25		—		—		67
Cash equivalents	1,182		17		—		—		1,199
Other investments	9		32		—		—		41
Total	$	2,208	$	1,864	$	—	$	156	$	4,228
Liabilities:
Energy-related derivatives(a)	$	3	$	7	$	—	$	—	$	10
Interest rate derivatives	—		139		—		—		139
Foreign currency derivatives	—		130		—		—		130
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	3	$	289	$	14	$	—	$	306

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(UNAUDITED)

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Alabama Power
Assets:
Energy-related derivatives	$	—	$	128	$	—	$	—	$	128
Nuclear decommissioning trusts:(b)
Domestic equity	452		193		—		—		645
Foreign equity	143		—		—		—		143
U.S. Treasury and government agency securities	—		21		—		—		21
Municipal bonds	—		2		—		—		2
Corporate bonds	1		253		—		—		254
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		156		156
Other	14		—		—		—		14
Cash equivalents	1,129		17		—		—		1,146
Other investments	—		32		—		—		32
Total	$	1,739	$	666	$	—	$	156	$	2,561
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Georgia Power
Assets:
Energy-related derivatives	$	—	$	179	$	—	$	—	$	179
Interest rate derivatives	—		12		—		—		12
Nuclear decommissioning trusts:(b)(c)
Domestic equity	302		1		—		—		303
Foreign equity	—		165		—		—		165
U.S. Treasury and government agency securities	—		269		—		—		269
Municipal bonds	—		51		—		—		51
Corporate bonds	—		237		—		—		237
Mortgage and asset backed securities	—		68		—		—		68
Other	28		25		—		—		53
Total	$	330	$	1,007	$	—	$	—	$	1,337
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1

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(UNAUDITED)

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Mississippi Power
Assets:
Energy-related derivatives	$	—	$	138	$	—	$	—	$	138
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Southern Power
Assets:
Energy-related derivatives	$	—	$	8	$	—	$	—	$	8
Liabilities:
Foreign currency derivatives	$	—	$	43	$	—	$	—	$	43
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	56	$	14	$	—	$	70
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	74	$	20	$	—	$	—	$	94
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		10		—		—		10
Cash equivalents	3		—		—		—		3
Total	$	77	$	40	$	—	$	—	$	117
Liabilities:
Energy-related derivatives(a)	$	3	$	1	$	—	$	—	$	4
Interest rate derivatives	—		36		—		—		36
Total	$	3	$	37	$	—	$	—	$	40

(a)Excludes cash collateral of $36 million.

(b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At March 31, 2022, approximately $72 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

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(UNAUDITED)

Southern Company, Alabama Power, and Georgia Power continue to elect the option to fair value investment securities held in the nuclear decommissioning trust funds. The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for the three months ended March 31, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended March 31, 2022		Three Months Ended March 31, 2021
	(in millions)
Southern Company	$	(150)	$	39
Alabama Power	(67)		41
Georgia Power	(83)		(2)

Valuation Methodologies

The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used.

For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available.

The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information.

Southern Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial.

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(UNAUDITED)

Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments.

"Other investments" include investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.

At March 31, 2022, the fair value measurements of private equity investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $156 million and unfunded commitments related to the private equity investments totaled $84 million. Private equity investments include high-quality private equity funds across several market sectors and funds that invest in real estate assets. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

At March 31, 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas(*)
	(in billions)
Long-term debt, including securities due within one year:
Carrying amount	$	51.6	$	9.8	$	13.2	$	1.5	$	3.7	$	6.9
Fair value	51.9		10.0		13.5		1.5		3.8		6.9

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043.

The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the current rates available to the Registrants.

(J) DERIVATIVES

The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 to the financial statements under "Financial Instruments" in Item 8 of the Form 10-K for additional information. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

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(UNAUDITED)

Energy-Related Derivatives

The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations.

Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in operating revenues.

Energy-related derivative contracts are accounted for under one of three methods:

•Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism.

•Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in accumulated OCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions.

•Not Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered.

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(UNAUDITED)

At March 31, 2022, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows:

	Net Purchased mmBtu	Longest Hedge Date	Longest Non-Hedge Date
	(in millions)
Southern Company(*)	279	2030	2025
Alabama Power	65	2025	—
Georgia Power	75	2024	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	64	2024	2025

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 66.2 million mmBtu and short natural gas positions of 2.6 million mmBtu at March 31, 2022, which is also included in Southern Company's total volume.

In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 18 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 6 million mmBtu for Georgia Power, 3 million mmBtu for Mississippi Power, and 5 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $29 million for Southern Company, $26 million for Southern Company Gas, and immaterial for all other Registrants.

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(UNAUDITED)

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

At March 31, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	200	1.87%	—	February 2032	$	8
Georgia Power	100		2.27%	—	November 2051	4
Cash Flow Hedges of Existing Debt
Southern Company parent	100		2.58%	—	April 2027	(1)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(29)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(69)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(35)
Southern Company	$	2,300				$	(122)

For cash flow hedge interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to interest expense for the 12-month period ending March 31, 2023 total $(20) million for Southern Company and are immaterial for all other Registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2051 for Southern Company, Alabama Power, and Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.

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Foreign Currency Derivatives

Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI.

At March 31, 2022, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(87)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	(24)
Southern Power	564		3.78%	500		1.85%	June 2026	(19)
Southern Power total	$	1,241		€	1,100			$	(43)
Southern Company	$	2,717		€	2,350			$	(130)

The estimated pre-tax losses related to Southern Power's foreign currency derivatives accounted for as cash flow hedges expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $17 million.

Derivative Financial Statement Presentation and Amounts

The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.

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(UNAUDITED)

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	381	$	1	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	116		6		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	497	$	7	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	28	$	2	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	5		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	17		3		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		136		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		59		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		71		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	50	$	271	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	16	$	2	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	17	$	2	$	10	$	4
Gross amounts recognized	$	564	$	280	$	238	$	153
Gross amounts offset(a)	(45)		(9)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	519	$	271	$	213	$	125

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	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	87	$	—	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	41		2		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	128	$	2	$	55	$	11
Gross amounts offset	(2)		(2)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	126	$	—	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	150	$	—	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	29		1		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	179	$	1	$	75	$	8
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	$	12	$	—	$	—	$	—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	12	$	—	$	—	$	—
Gross amounts recognized	$	191	$	1	$	75	$	8
Gross amounts offset	(1)		(1)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	190	$	—	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	94	$	—	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	44		2		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	138	$	2	$	56	$	5
Gross amounts offset	(2)		(2)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	136	$	—	$	52	$	1

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	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	3	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	3		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		35		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		8		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	6	$	43	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	2	$	—	$	1	$	—
Gross amounts recognized	$	8	$	43	$	4	$	16
Gross amounts offset	—		—		—		—
Net amounts recognized in the Balance Sheets	$	8	$	43	$	4	$	16

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	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	49	$	1	$	15	$	12
Other deferred charges and assets/Other deferred credits and liabilities	3		—		—		—
Total derivatives designated as hedging instruments for regulatory purposes	$	52	$	1	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	25	$	2	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	27	$	38	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	14	$	1	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	15	$	1	$	9	$	4
Gross amounts recognized	$	94	$	40	$	35	$	27
Gross amounts offset(a)	(40)		(4)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	54	$	36	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $36 million and $3 million at March 31, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at March 31, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.

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At March 31, 2022 and December 31, 2021, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows:

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet
Derivative Category and Balance Sheet Location	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Company Gas
	(in millions)
At March 31, 2022:
Energy-related derivatives:
Other regulatory liabilities, current	$	353	$	87	$	150	$	94	$	22
Other regulatory liabilities, deferred	111		39		28		42		2
Total energy-related derivative gains (losses)	$	464	$	126	$	178	$	136	$	24
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

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For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	42	$	5
Interest rate derivatives	9		3
Foreign currency derivatives	(28)		(47)
Fair value hedges(*):
Foreign currency derivatives	4		—
Total	$	27	$	(39)
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	12	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	5	$	4
Foreign currency derivatives	(28)		(47)
Total	$	(23)	$	(43)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	37	$	1

(*)Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other Registrants.

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(UNAUDITED)

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		(3)
Total depreciation and amortization	892		871
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(462)		(450)
Gain (loss) on interest rate cash flow hedges(a)	(7)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Gain (loss) on interest rate fair value hedges(b)	(123)		(10)
Total other income (expense), net	145		58
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Gain (loss) on foreign currency fair value hedges	(24)		—
Amount excluded from effectiveness testing recognized in earnings	(4)		—
Southern Power
Total depreciation and amortization	$	120	$	119
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(37)		(38)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Total other income (expense), net	2		7
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Southern Company Gas
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		—
Total interest expense, net of amounts capitalized	(61)		(60)
Gain (loss) on interest rate cash flow hedges(a)	(1)		—
Gain (loss) on interest rate fair value hedges(b)	(36)		—

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income for energy-related derivatives and interest rate derivatives were immaterial for the traditional electric operating companies.

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(UNAUDITED)

At March 31, 2022 and December 31, 2021, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges:

	Carrying Amount of the Hedged Item				Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item
Balance Sheet Location of Hedged Items	At March 31, 2022		At December 31, 2021		At March 31, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,136)	$	(3,280)	$	126	$	9
Southern Company Gas
Long-term debt	$	(459)	$	(493)	$	37	$	2

For the three months ended March 31, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	2	$	(17)
	Cost of natural gas	21		7
Total derivatives in non-designated hedging relationships		$	23	$	(10)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives not designated as hedging instruments were immaterial for Southern Company and Southern Company Gas and the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for all other Registrants.

Contingent Features

The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At March 31, 2022, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the applicable Registrants, the fair value of interest rate and energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at March 31, 2022. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the sale of Gulf Power to NextEra Energy, Inc., Gulf Power has continued participating in the Southern Company power pool; however, the parties currently expect this participation to end during the third quarter 2022.

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(UNAUDITED)

Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts recognized for derivatives executed with the same counterparty.

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin requirements. At March 31, 2022, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2022, cash collateral held on deposit in broker margin accounts was $36 million.

The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk.

Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables.

The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance.

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(K) ACQUISITIONS AND DISPOSITIONS

See Note 15 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Power

Construction Projects

During the three months ended March 31, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility.

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Three Months Ended March 31, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

(L) SEGMENT AND RELATED INFORMATION

Southern Company

The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The traditional electric operating companies are vertically integrated utilities providing electric service in three Southeastern states. Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy and battery energy storage projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through its natural gas distribution utilities and is involved in several other complementary businesses including gas pipeline investments and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' other businesses also included wholesale gas services.

Southern Company's reportable business segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Revenues from sales by Southern Power to the traditional electric operating companies were $105 million and $81 million for the three months ended March 31, 2022 and 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for both periods presented. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $12 million for the three months ended March 31, 2021, which represented sales from Sequent prior to its sale. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications and, for the three months ended March 31, 2021, leveraged lease projects. All other inter-segment revenues are not material.

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(UNAUDITED)

Financial data for business segments and products and services for the three months ended March 31, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At March 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	90,460		13,766		(627)		103,599		23,377		4,236		(2,573)		128,639
Three Months Ended March 31, 2021
Operating revenues	$	3,764	$	440	$	(87)	$	4,117	$	1,694	$	134	$	(35)	$	5,910
Segment net income (loss)(a)(b)(c)	756		97		—		853		398		(108)		(8)		1,135
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes a pre-tax charge of $48 million ($36 million after tax) at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	3,613	$	664	$	232	$	4,509
Three Months Ended March 31, 2021	3,342		545		230		4,117

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	1,791	$	—	$	243	$	24	$	2,058
Three Months Ended March 31, 2021	1,192		298		195		9		1,694

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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(UNAUDITED)

Southern Company Gas

Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the sale of Sequent.

Gas distribution operations is the largest component of Southern Company Gas' business and includes natural gas local distribution utilities that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in four states.

Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a 50% interest in SNG and a 50% joint ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the customers of Southern Company Gas. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar.

The all other column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage and fuels operations.

Business segment financial data for the three months ended March 31, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(*)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	—	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income (loss)	214		29		—		66		309		10		—		319
Total assets at March 31, 2022	21,034		1,473		—		1,640		24,147		12,017		(12,787)		23,377
Three Months Ended March 31, 2021
Operating revenues	$	1,200	$	8	$	298	$	195	$	1,701	$	7	$	(14)	$	1,694
Segment net income (loss)	183		29		126		56		394		4		—		398
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three months ended March 31, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2021	$	2,588	$	63	$	2,651	$	2,353	$	298

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Item 2. Management's Discussion and Analysis of Financial Condition and Results of Operations.

	Page
Combined Management's Discussion and Analysis of Financial Condition and Results of Operations
Overview	87
Results of Operations	88
Southern Company	88
Alabama Power	95
Georgia Power	99
Mississippi Power	103
Southern Power	106
Southern Company Gas	109
Future Earnings Potential	115
Accounting Policies	117
Financial Condition and Liquidity	118

The following Management's Discussion and Analysis of Financial Condition and Results of Operations is a combined presentation; however, information contained herein relating to any individual Registrant is filed by such Registrant on its own behalf and each Registrant makes no representation as to information related to the other Registrants.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS

OVERVIEW

Southern Company is a holding company that owns all of the common stock of three traditional electric operating companies (Alabama Power, Georgia Power, and Mississippi Power), Southern Power, and Southern Company Gas and owns other direct and indirect subsidiaries. The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. Southern Company's reportable segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Southern Company Gas' reportable segments are gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. See Note (L) to the Condensed Financial Statements herein for additional information on segment reporting. For additional information on the Registrants' primary business activities and the sale of Sequent, see BUSINESS – "The Southern Company System" in Item 1 of the Form 10-K and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K, respectively.

The Registrants continue to focus on several key performance indicators. For the traditional electric operating companies and Southern Company Gas, these indicators include, but are not limited to, customer satisfaction, plant availability, electric and natural gas system reliability, and execution of major construction projects. For Southern Power, these indicators include, but are not limited to, the equivalent forced outage rate and contract availability to evaluate operating results and help ensure its ability to meet its contractual commitments to customers. In addition, Southern Company and the Subsidiary Registrants focus on earnings per share and net income, respectively, as a key performance indicator.

Recent Developments

Georgia Power

Plant Vogtle Units 3 and 4 Construction and Start-Up Status

Construction continues on Plant Vogtle Units 3 and 4 (with electric generating capacity of approximately 1,100 MWs each), in which Georgia Power currently holds a 45.7% ownership interest. Georgia Power's share of the total project capital cost forecast to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is $10.4 billion.

Fuel load for Unit 3 is projected during the third quarter or the fourth quarter 2022 with an in-service date projected during the fourth quarter 2022 or the first quarter 2023. Unit 3's projected schedule primarily depends on improvements in overall construction productivity and production levels, the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the third quarter or the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on overall construction productivity and production levels improving as well as appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates.

Georgia Power and the other Vogtle Owners do not agree on the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments (as defined in Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction – Joint Owner Contracts" herein). The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 180 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

During the first quarter 2022, established construction contingency totaling $43 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, and support resources for Units 3 and 4.

The ultimate impact of these matters on the construction schedule and project capital cost forecast for Plant Vogtle Units 3 and 4 cannot be determined at this time. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information.

Rate Plan

Georgia Power is required to file its next general base rate case by June 24, 2022. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Mississippi Power

On March 15, 2022, Mississippi Power submitted its annual retail PEP filing for 2022 to the Mississippi PSC, which requested a 1.9%, or approximately $18 million, annual increase in revenues. In accordance with the PEP rate schedule, the rate increase became effective with the first billing cycle of April 2022, subject to refund. The related proceedings are expected to conclude in summer 2022; however, the ultimate outcome of this matter cannot be determined at this time.

Southern Power

During the three months ended March 31, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

At March 31, 2022, Southern Power's average investment coverage ratio for its generating assets, including those owned with various partners, based on the ratio of investment under contract to total investment using the respective facilities' net book value (or expected in-service value for facilities under construction) as the investment amount was 95% through 2026 and 92% through 2031, with an average remaining contract duration of approximately 13 years.

Southern Company Gas

On April 7, 2022, Virginia Natural Gas notified the Virginia State Corporation Commission of its intent to file a base rate case in the third quarter 2022. The ultimate outcome of this matter cannot be determined at this time.

RESULTS OF OPERATIONS

Southern Company

Net Income

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(103)	(9.1)

Consolidated net income attributable to Southern Company was $1.0 billion ($0.97 per share) for first quarter 2022 compared to $1.1 billion ($1.07 per share) for the corresponding period in 2021. The decrease was primarily due to the first quarter 2021 net income of $126 million at Sequent, which was sold on July 1, 2021, and higher non-fuel operations and maintenance costs, partially offset by an increase in natural gas revenues from base rate increases and continued infrastructure replacement, an increase in retail electric revenues primarily from base tariff increases in accordance with Georgia Power's 2019 ARP, and a $36 million after-tax charge in the first quarter 2021 related to the construction of Plant Vogtle Units 3 and 4.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Retail Electric Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$271	8.1

In the first quarter 2022, retail electric revenues were $3.6 billion compared to $3.3 billion for the corresponding period in 2021.

Details of the changes in retail electric revenues were as follows:

	First Quarter 2022
	(in millions)		(% change)
Retail electric – prior year	$	3,342
Estimated change resulting from –
Rates and pricing	56		1.7	%
Sales growth	20		0.6
Weather	16		0.5
Fuel and other cost recovery	179		5.3
Retail electric – current year	$	3,613	8.1	%

Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared to the corresponding period in 2021. The increase was primarily due to base tariff increases in accordance with Georgia Power's 2019 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021. Weather-adjusted residential KWH sales decreased 1.1% and weather-adjusted commercial KWH sales increased 1.9% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions. Increased customer growth partially offset the decrease in residential KWH sales and contributed to the increase in commercial KWH sales. Industrial KWH sales increased 1.7% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to strength in the pipeline segment.

Fuel and other cost recovery revenues increased $179 million in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher fuel and purchased power costs. Electric rates for the traditional electric operating companies include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of PPA costs, and do not affect net income. The traditional electric operating companies each have one or more regulatory mechanisms to recover other costs such as environmental and other compliance costs, storm damage, new plants, and PPA capacity costs.

Wholesale Electric Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$119	21.8

In the first quarter 2022, wholesale electric revenues were $664 million compared to $545 million for the corresponding period in 2021. The increase was primarily due to a $117 million increase in energy revenues in the first quarter 2022 as a result of higher natural gas prices when compared to the corresponding period in 2021 and an increase in the volume of KWHs sold at Southern Power primarily associated with natural gas PPAs.

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AND RESULTS OF OPERATIONS (Continued)

Wholesale electric revenues consist of revenues from PPAs and short-term opportunity sales. Wholesale electric revenues from PPAs (other than solar and wind PPAs) have both capacity and energy components. Capacity revenues generally represent the greatest contribution to net income and are designed to provide recovery of fixed costs plus a return on investment. Energy revenues will vary depending on fuel prices, the market prices of wholesale energy compared to the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Energy sales from solar and wind PPAs do not have a capacity charge and customers either purchase the energy output of a dedicated renewable facility through an energy charge or through a fixed price related to the energy. As a result, the ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors. Wholesale electric revenues at Mississippi Power include FERC-regulated municipal and rural association sales under cost-based tariffs as well as market-based sales. Short-term opportunity sales are made at market-based rates that generally provide a margin above the Southern Company system's variable cost to produce the energy.

Natural Gas Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$364	21.5

In the first quarter 2022, natural gas revenues were $2.1 billion compared to $1.7 billion for the corresponding period in 2021.

Details of the changes in natural gas revenues were as follows:

	First Quarter 2022
	(in millions)		(% change)
Natural gas revenues – prior year	$	1,694
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	86		5.1	%
Gas costs and other cost recovery	544		32.1
Gas marketing services	18		1.1
Wholesale gas services	(297)		(17.5)
Other	13		0.7
Natural gas revenues – current year	$	2,058	21.5	%

Revenues from infrastructure replacement programs and base rate changes at the natural gas distribution utilities increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to rate increases at Atlanta Gas Light and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

Revenues associated with gas costs and other cost recovery increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. Natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from the natural gas distribution utilities.

Revenues from gas marketing services increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher commodity prices and higher sales to commercial customers.

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AND RESULTS OF OPERATIONS (Continued)

The change in revenues related to Southern Company Gas' wholesale gas services was due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Other Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(23)	(14.5)

In the first quarter 2022, other revenues were $136 million compared to $159 million for the corresponding period in 2021. The decrease was primarily due to a $14 million decrease at PowerSecure primarily related to distributed infrastructure and energy efficiency projects and a $6 million decrease in unregulated sales associated with power delivery construction and maintenance projects at Georgia Power.

Fuel and Purchased Power Expenses

	First Quarter 2022 vs. First Quarter 2021
	(change in millions)		(% change)
Fuel	$	263	31.0
Purchased power	25		12.1
Total fuel and purchased power expenses	$	288

In the first quarter 2022, total fuel and purchased power expenses were $1.3 billion compared to $1.1 billion for the corresponding period in 2021. The increase was primarily the result of a $247 million increase in the average cost of fuel and purchased power and a $41 million increase in the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions at the traditional electric operating companies are generally offset by fuel revenues and do not have a significant impact on net income. See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information. Fuel expenses incurred under Southern Power's PPAs are generally the responsibility of the counterparties and do not significantly impact net income.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Details of the Southern Company system's generation and purchased power were as follows:

	First Quarter 2022	First Quarter 2021
Total generation (in billions of KWHs)(a)	46	43
Total purchased power (in billions of KWHs)	4	4
Sources of generation (percent)(a) —
Gas	46	46
Coal	23	24
Nuclear	17	17
Hydro	6	5
Wind, Solar, and Other	8	8
Cost of fuel, generated (in cents per net KWH)—
Gas(a)	3.53	2.55
Coal	3.11	2.82
Nuclear	0.72	0.75
Average cost of fuel, generated (in cents per net KWH)(a)	2.86	2.26
Average cost of purchased power (in cents per net KWH)(b)	5.58	5.10

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

(b)Average cost of purchased power includes fuel purchased by the Southern Company system for tolling agreements where power is generated by the provider.

Fuel

In the first quarter 2022, fuel expense was $1.1 billion compared to $0.8 billion for the corresponding period in 2021. The increase was primarily due to a 38.4% increase in the average cost of natural gas per KWH generated, a 10.3% increase in the average cost of coal per KWH generated, and a 4.6% increase in the volume of KWHs generated by natural gas, partially offset by a 41.2% increase in the volume of KWHs generated by hydro.

Purchased Power

In the first quarter 2022, purchased power expense was $232 million compared to $207 million for the corresponding period in 2021. The increase was primarily due to a 9.4% increase in the average cost per KWH purchased primarily due to higher natural gas prices and a 4.6% increase in the volume of KWHs purchased.

Energy purchases will vary depending on demand for energy within the Southern Company system's electric service territory, the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, and the availability of the Southern Company system's generation.

Cost of Natural Gas

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$512	87.8

Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

the natural gas distribution utilities. Cost of natural gas at the natural gas distribution utilities represented 90% of total cost of natural gas for the first quarter 2022.

In the first quarter 2022, cost of natural gas was $1.1 billion compared to $0.6 billion for the corresponding period in 2021. The increase reflects higher gas cost recovery as a result of an 83.9% increase in natural gas prices in the first quarter 2022 compared to the corresponding period in 2021.

Cost of Other Sales

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(13)	(15.9)

In the first quarter 2022, cost of other sales was $69 million compared to $82 million for the corresponding period in 2021. The decrease was primarily due to decreases of $9 million at Georgia Power primarily associated with unregulated power delivery construction and maintenance projects and $4 million related to distributed infrastructure and energy efficiency projects at PowerSecure.

Other Operations and Maintenance Expenses

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$144	10.5

In the first quarter 2022, other operations and maintenance expenses were $1.5 billion compared to $1.4 billion for the corresponding period in 2021. Excluding $48 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased $192 million. The increase was primarily due to increases of $66 million in transmission and distribution expenses primarily related to line maintenance, $58 million in generation expenses primarily related to scheduled outage and maintenance, and $16 million in expenses at Southern Company Gas passed through directly to customers, primarily related to bad debt.

Depreciation and Amortization

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$21	2.4

In the first quarter 2022, depreciation and amortization was $892 million compared to $871 million for the corresponding period in 2021. The increase was primarily due to additional plant in service.

Taxes Other Than Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$27	7.8

In the first quarter 2022, taxes other than income taxes were $372 million compared to $345 million for the corresponding period in 2021. The increase primarily reflects an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas and an increase in municipal franchise fees related to higher retail revenues at Georgia Power.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Estimated Loss on Plant Vogtle Units 3 and 4

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(48)	N/M

N/M - Not meaningful

In the first quarter 2021, a $48 million estimated probable loss on Plant Vogtle Units 3 and 4 was recorded at Georgia Power. The loss reflects revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

Gain on Dispositions, Net

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(21)	(47.7)

In the first quarter 2022, gain on dispositions, net was $23 million compared to $44 million for the corresponding period in 2021. The first quarter 2022 amount includes $17 million in gains from sales of integrated transmission system assets at Georgia Power. The first quarter 2021 amount includes $39 million in gains at Southern Power primarily from contributions of wind turbine equipment to various equity method investments. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Interest Expense, Net of Amounts Capitalized

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$12	2.7

In the first quarter 2022, interest expense, net of amounts capitalized was $462 million compared to $450 million for the corresponding period in 2021. The increase was primarily due to higher average outstanding borrowings, partially offset by lower interest rates on newly issued debt relative to the debt that was retired since the first quarter 2021.

Other Income (Expense), Net

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$87	150.0

In the first quarter 2022, other income (expense), net was $145 million compared to $58 million for the corresponding period in 2021. The increase was primarily due to $75 million in charitable contributions at Southern Company Gas in the first quarter 2021 and a $13 million increase in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(17)	(8.9)

In the first quarter 2022, income taxes were $173 million compared to $190 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $40 million at Southern Company Gas' wholesale gas services business as a result of the sale of Sequent on July 1, 2021, partially offset by $16 million of tax benefits in the first quarter 2021 resulting from new legislation that changed Southern Power's state apportionment methodology. See Note (G) to the Condensed Financial Statements herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$13	40.6

Substantially all noncontrolling interests relate to renewable projects at Southern Power. In the first quarter 2022, net loss attributable to noncontrolling interests was $45 million compared to $32 million for the corresponding period in 2021. The increased loss was primarily due to loss allocations to Southern Power's partners in the Garland and Tranquillity battery energy storage facilities and higher HLBV loss allocations to Southern Power's wind tax equity partners, including new partnerships entered into during 2021. The increased loss allocations were partially offset by higher income allocations to Southern Power's solar equity partners.

Alabama Power

Net Income

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(12)	(3.3)

Alabama Power's net income after dividends on preferred stock in the first quarter 2022 was $347 million compared to $359 million for the corresponding period in 2021. The decrease was primarily due to an increase in non-fuel operations and maintenance expenses, partially offset by an increase in retail revenues resulting from sales growth in the first quarter 2022 compared to the corresponding period in 2021.

Retail Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$27	2.0

In the first quarter 2022, retail revenues were $1.38 billion compared to $1.35 billion for the corresponding period in 2021.

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AND RESULTS OF OPERATIONS (Continued)

Details of the changes in retail revenues were as follows:

	First Quarter 2022
	(in millions)		(% change)
Retail – prior year	$	1,352
Estimated change resulting from –
Rates and pricing	—		—	%
Sales growth	14		1.0
Weather	1		0.1
Fuel and other cost recovery	12		0.9
Retail – current year	$	1,379	2.0	%

Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021. Weather-adjusted residential and commercial KWH sales increased 0.6% and 1.0%, respectively, in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to customer growth. Industrial KWH sales increased 0.1% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to a recovering industrial class that continues to experience disruptions in supply chain and business operations.

Fuel and other cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to increases in the volume of KWHs generated and the average cost of fuel.

Electric rates include provisions to recognize the recovery of fuel costs, purchased power costs, PPAs certificated by the Alabama PSC, and costs associated with the NDR. Under these provisions, fuel and other cost recovery revenues generally equal fuel and other cost recovery expenses and do not affect net income. See Note 2 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

Wholesale Revenues – Non-Affiliates

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$22	23.9

In the first quarter 2022, wholesale revenues from sales to non-affiliates were $114 million compared to $92 million for the corresponding period in 2021. The increase was primarily due to a 16.2% increase in KWH sales as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021, as well as a 6.0% increase in the price of energy due to higher natural gas prices.

Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Alabama Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not affect net income. Short-term opportunity energy sales are also included in wholesale energy sales to non-affiliates. These opportunity sales are made at market-based rates that generally provide a margin above Alabama Power's variable cost to produce the energy.

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AND RESULTS OF OPERATIONS (Continued)

Wholesale Revenues – Affiliates

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$33	103.1

In the first quarter 2022, wholesale revenues from sales to affiliates were $65 million compared to $32 million for the corresponding period in 2021. The increase was primarily due to a 47.1% increase in the price of energy due to higher natural gas prices and a 40.3% increase in KWH sales as a result of increased generation demand as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021.

Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost and energy purchases are generally offset by energy revenues through Alabama Power's energy cost recovery clause.

Fuel and Purchased Power Expenses

	First Quarter 2022 vs. First Quarter 2021
	(change in millions)		(% change)
Fuel	$	42	14.4
Purchased power – non-affiliates	17		34.0
Purchased power – affiliates	(4)		(13.3)
Total fuel and purchased power expenses	$	55

In the first quarter 2022, total fuel and purchased power expenses were $426 million compared to $371 million for the corresponding period in 2021. The increase was primarily due to a $39 million increase in the average cost of fuel and purchased power and a $16 million increase related to the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions do not have a significant impact on earnings, since energy expenses are generally offset by energy revenues through Alabama Power's energy cost recovery clause. See Note 2 to the financial statements under "Alabama Power – Rate ECR" in Item 8 of the Form 10-K for additional information.

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AND RESULTS OF OPERATIONS (Continued)

Details of Alabama Power's generation and purchased power were as follows:

	First Quarter 2022	First Quarter 2021
Total generation (in billions of KWHs)(a)	15	15
Total purchased power (in billions of KWHs)	2	1
Sources of generation (percent)(a) —
Coal	42	46
Nuclear	25	25
Gas	19	19
Hydro	14	10
Cost of fuel, generated (in cents per net KWH) —
Coal	2.90	2.75
Nuclear	0.67	0.72
Gas(a)	3.45	2.51
Average cost of fuel, generated (in cents per net KWH)(a)	2.36	2.14
Average cost of purchased power (in cents per net KWH)(b)	6.82	6.52

(a)Excludes Central Alabama Generating Station KWHs and associated cost of fuel as its fuel is provided by the purchaser under a power sales agreement. See Note 15 to the financial statements under "Alabama Power" in Item 8 of the Form 10-K for additional information.

(b)Average cost of purchased power includes fuel, energy, and transmission purchased by Alabama Power for tolling agreements where power is generated by the provider.

Fuel

In the first quarter 2022, fuel expense was $333 million compared to $291 million for the corresponding period in 2021. The increase was primarily due to a 37.5% increase in the average cost of natural gas per KWH generated, which excludes tolling agreements, and a 6.3% increase in the volume of KWHs generated by natural gas, partially offset by a 49.0% increase in the volume of KWHs generated by hydro.

Purchased Power – Non-Affiliates

In the first quarter 2022, purchased power expense from non-affiliates was $67 million compared to $50 million for the corresponding period in 2021. The increase was primarily due to a 29.9% increase in the volume of KWHs purchased as a result of cooler weather in 2022 compared to the corresponding period in 2021, as well as a 9.8% increase in the average cost per KWH purchased due to higher natural gas prices.

Energy purchases from non-affiliates will vary depending on the market prices of wholesale energy as compared to the cost of the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation.

Purchased Power – Affiliates

For first quarter 2022, purchased power expense from affiliates was $26 million compared to $30 million for the corresponding period in 2021. The decrease was primarily due to a 17.7% decrease in the volume of KWHs purchased as a result of increased generation compared to the corresponding period in 2021, partially offset by a 5.6% increase in the average cost per KWH purchased due to higher natural gas prices.

Energy purchases from affiliates will vary depending on demand for energy and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, as approved by the FERC.

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Other Operations and Maintenance Expenses

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$48	13.3

In the first quarter 2022, other operations and maintenance expenses were $409 million compared to $361 million for the corresponding period in 2021. The increase was primarily due to increases of $26 million in generation expenses associated with scheduled outages and maintenance and Rate CNP Compliance-related expenses and $12 million in transmission and distribution expenses primarily associated with line maintenance. See Note 2 to the financial statements under "Alabama Power – Rate CNP Compliance" in Item 8 of the Form 10-K for additional information.

Georgia Power

Net Income

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$34	9.7

Georgia Power's net income in the first quarter 2022 was $385 million compared to $351 million for the corresponding period in 2021. The increase was primarily due to higher retail revenues primarily from base tariff increases in accordance with the 2019 ARP and a $36 million after-tax charge in the first quarter 2021 related to the construction of Plant Vogtle Units 3 and 4, partially offset by higher non-fuel operations and maintenance costs. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information regarding Plant Vogtle Units 3 and 4.

Retail Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$230	12.9

In the first quarter 2022, retail revenues were $2.02 billion compared to $1.79 billion for the corresponding period in 2021.

Details of the changes in retail revenues were as follows:

	First Quarter 2022
	(in millions)		(% change)
Retail – prior year	$	1,787
Estimated change resulting from –
Rates and pricing	53		3.0	%
Sales growth	2		0.1
Weather	18		1.0
Fuel cost recovery	157		8.8
Retail – current year	$	2,017	12.9	%

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AND RESULTS OF OPERATIONS (Continued)

Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared to the corresponding period in 2021. The increase was primarily due to base tariff increases in accordance with the 2019 ARP. See Note 2 to the financial statements under "Georgia Power – Rate Plans" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021. Weather-adjusted residential KWH sales decreased 2.3% and weather-adjusted commercial KWH sales increased 2.2% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to the impacts on customer usage from increased activity outside the home following the expiration of COVID-19 restrictions. Increased customer growth partially offset the decrease in residential KWH sales and contributed to the increase in commercial KWH sales. Weather-adjusted industrial KWH sales increased 3.6% in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to strength in the pipeline segment.

Fuel revenues and costs are allocated between retail and wholesale jurisdictions. Retail fuel cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 due to higher fuel and purchased power costs. Electric rates include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these fuel cost recovery provisions, fuel revenues generally equal fuel expenses and do not affect net income. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.

Wholesale Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$23	53.5

In the first quarter 2022, wholesale revenues were $66 million compared to $43 million for the corresponding period in 2021. The increase was primarily due to increases of $18 million related to the average cost of fuel primarily due to higher natural gas and coal prices and $7 million in KWH sales associated with higher market demand as a result of cooler weather in the first quarter 2022 compared to the corresponding period in 2021, partially offset by a decrease of $4 million in capacity revenues from shared Southern Company power pool sales in accordance with the IIC.

Wholesale revenues from sales to non-affiliates consist of PPAs and short-term opportunity sales. Wholesale revenues from PPAs have both capacity and energy components. Wholesale capacity revenues from PPAs are recognized in amounts billable under the contract terms and provide for recovery of fixed costs and a return on investment. Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Georgia Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. Short-term opportunity sales are made at market-based rates that generally provide a margin above Georgia Power's variable cost of energy.

Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.

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AND RESULTS OF OPERATIONS (Continued)

Other Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(15)	(10.7)

In the first quarter 2022, other revenues were $125 million compared to $140 million for the corresponding period in 2021. The decrease was primarily due to decreases of $8 million resulting from the termination of a transmission service contract and $6 million in unregulated sales associated with power delivery construction and maintenance projects.

Fuel and Purchased Power Expenses

	First Quarter 2022 vs. First Quarter 2021
	(change in millions)		(% change)
Fuel	$	106	33.9
Purchased power – non-affiliates	6		4.2
Purchased power – affiliates	70		51.5
Total fuel and purchased power expenses	$	182

In the first quarter 2022, total fuel and purchased power expenses were $775 million compared to $593 million for the corresponding period in 2021. The increase was due to an increase of $133 million related to the average cost of fuel and purchased power and an increase of $49 million related to the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions do not have a significant impact on earnings since these fuel expenses are generally offset by fuel revenues through Georgia Power's fuel cost recovery mechanism. See Note 2 to the financial statements under "Georgia Power – Fuel Cost Recovery" in Item 8 of the Form 10-K for additional information.

Details of Georgia Power's generation and purchased power were as follows:

	First Quarter 2022	First Quarter 2021
Total generation (in billions of KWHs)	15	14
Total purchased power (in billions of KWHs)	8	7
Sources of generation (percent) —
Gas	46	47
Coal	25	22
Nuclear	24	27
Hydro and other	5	4
Cost of fuel, generated (in cents per net KWH) —
Gas	3.58	2.58
Coal	3.41	2.91
Nuclear	0.77	0.78
Average cost of fuel, generated (in cents per net KWH)	2.83	2.15
Average cost of purchased power (in cents per net KWH)(*)	4.81	4.22

(*)Average cost of purchased power includes fuel purchased by Georgia Power for tolling agreements where power is generated by the provider.

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AND RESULTS OF OPERATIONS (Continued)

Fuel

In the first quarter 2022, fuel expense was $419 million compared to $313 million for the corresponding period in 2021. The increase was primarily due to increases of 38.8% and 17.2% in the average cost per KWH generated by natural gas and coal, respectively, and a 19.5% increase in the volume of KWHs generated by coal.

Purchased Power – Affiliates

In the first quarter 2022, purchased power expense from affiliates was $206 million compared to $136 million for the corresponding period in 2021. The increase was primarily due to an increase of 25.7% in the average cost per KWH purchased primarily due to higher natural gas and coal prices and an increase of 18.3% in the volume of KWHs purchased due to lower cost Southern Company system resources as compared to available Georgia Power-owned generation.

Energy purchases from affiliates will vary depending on the demand and the availability and cost of generating resources at each company within the Southern Company system. These purchases are made in accordance with the IIC or other contractual agreements, all as approved by the FERC.

Other Operations and Maintenance Expenses

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$43	9.1

In the first quarter 2022, other operations and maintenance expenses were $517 million compared to $474 million for the corresponding period in 2021. The increase was primarily due to increases of $45 million in transmission and distribution expenses primarily associated with line maintenance and $19 million in generation expenses primarily related to non-outage maintenance costs, partially offset by $17 million in gains from sales of integrated transmission system assets and a $9 million reduction in billing adjustments with integrated transmission system owners largely resulting from a terminated transmission service agreement.

Depreciation and Amortization

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$13	3.8

In the first quarter 2022, depreciation and amortization was $351 million compared to $338 million for the corresponding period in 2021. The increase was primarily due to additional plant in service.

Taxes Other Than Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$9	7.8

In the first quarter 2022, taxes other than income taxes was $125 million compared to $116 million for the corresponding period in 2021. The increase was primarily due to an increase in municipal franchise fees largely related to higher retail revenues.

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AND RESULTS OF OPERATIONS (Continued)

Estimated Loss on Plant Vogtle Units 3 and 4

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(48)	N/M

N/M - Not meaningful

In the first quarter 2021, a $48 million estimated probable loss on Plant Vogtle Units 3 and 4 was recorded at Georgia Power. The loss reflects revisions to the total project capital cost forecast to complete construction and start-up of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

Other Income (Expense), Net

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$9	22.0

In the first quarter 2022, other income (expense), net was $50 million compared to $41 million for the corresponding period in 2021. The increase was primarily due to increases of $3 million in customer charges related to contributions in aid of construction and $3 million in non-service cost-related retirement benefits income. See Note (H) to the Condensed Financial Statements herein for additional information on retirement benefits.

Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$12	66.7

In the first quarter 2022, income taxes were $30 million compared to $18 million for the corresponding period in 2021. The increase was primarily due to the reduction in pre-tax earnings in the first quarter 2021 resulting from a charge associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements herein and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

Mississippi Power

Net Income

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(3)	(6.7)

Mississippi Power's net income in the first quarter 2022 was $42 million compared to $45 million for the corresponding period in 2021. The decrease was primarily due to an increase in operations and maintenance expenses, largely offset by an increase in revenues.

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AND RESULTS OF OPERATIONS (Continued)

Retail Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$13	6.4

In the first quarter 2022, retail revenues were $217 million compared to $204 million for the corresponding period in 2021.

Details of the changes in retail revenues were as follows:

	First Quarter 2022
	(in millions)		(% change)
Retail – prior year	$	204
Estimated change resulting from –
Rates and pricing	3		1.5	%
Sales growth	1		0.5
Weather	(2)		(1.0)
Fuel and other cost recovery	11		5.4
Retail – current year	$	217	6.4	%

Revenues associated with changes in rates and pricing increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to new PEP rates that became effective for the first billing cycle of April 2021. See Note 2 to the financial statements under "Mississippi Power – Performance Evaluation Plan" in Item 8 of the Form 10-K for additional information.

Revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021. Weather-adjusted residential and commercial KWH sales increased 0.8% and 2.9%, respectively, in the first quarter 2022 when compared to the corresponding period in 2021 due to increased customer usage and customer growth. Industrial KWH sales decreased 0.1% in the first quarter 2022 when compared to the corresponding period in 2021.

Fuel and other cost recovery revenues increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily as a result of higher recoverable fuel costs. Recoverable fuel costs include fuel and purchased power expenses reduced by the fuel portion of wholesale revenues from energy sold to customers outside Mississippi Power's service territory. Electric rates include provisions to adjust billings for fluctuations in fuel costs, including the energy component of purchased power costs. Under these provisions, fuel revenues generally equal fuel expenses, including the energy component of purchased power costs, and do not affect net income.

Wholesale Revenues – Non-Affiliates

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$5	7.9

In the first quarter 2022, wholesale revenues from sales to non-affiliates were $68 million compared to $63 million for the corresponding period in 2021. The increase was primarily due to higher fuel costs and customer usage.

Wholesale revenues from sales to non-affiliates will vary depending on fuel prices, the market prices of wholesale energy compared to the cost of Mississippi Power's and the Southern Company system's generation, demand for energy within the Southern Company system's electric service territory, and the availability of the Southern Company system's generation. Increases and decreases in energy revenues that are driven by fuel prices are

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AND RESULTS OF OPERATIONS (Continued)

accompanied by an increase or decrease in fuel costs and do not have a significant impact on net income. In addition, Mississippi Power provides service under long-term contracts with rural electric cooperative associations and municipalities located in southeastern Mississippi under cost-based electric tariffs which are subject to regulation by the FERC. See Note 2 to the financial statements under "Mississippi Power" in Item 8 of the Form 10-K for additional information.

Wholesale Revenues – Affiliates

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$9	27.3

In the first quarter 2022, wholesale revenues from sales to affiliates were $42 million compared to $33 million for the corresponding period in 2021. The increase was primarily due to an increase of $14 million associated with higher natural gas prices, partially offset by a decrease of $4 million associated with lower KWH sales.

Wholesale revenues from sales to affiliated companies will vary depending on demand and the availability and cost of generating resources at each company. These affiliate sales are made in accordance with the IIC, as approved by the FERC. These transactions do not have a significant impact on earnings since this energy is generally sold at marginal cost.

Fuel and Purchased Power Expenses

	First Quarter 2022 vs. First Quarter 2021
	(change in millions)		(% change)
Fuel	$	26	24.5
Purchased power	—		—
Total fuel and purchased power expenses	$	26

In the first quarter 2022, total fuel and purchased power expenses were $132 million compared to $106 million for the corresponding period in 2021. The increase was primarily due to a $33 million increase in the average cost of fuel, partially offset by a $7 million decrease associated with the volume of KWHs generated and purchased.

Fuel and purchased power energy transactions do not have a significant impact on earnings since energy expenses are generally offset by energy revenues through Mississippi Power's fuel cost recovery clause.

Details of Mississippi Power's generation and purchased power were as follows:

	First Quarter 2022	First Quarter 2021
Total generation (in millions of KWHs)	4,074	4,324
Total purchased power (in millions of KWHs)	120	121
Sources of generation (percent) –
Gas	92	91
Coal	8	9
Cost of fuel, generated (in cents per net KWH) –
Gas	3.30	2.41
Coal	3.74	3.17
Average cost of fuel, generated (in cents per net KWH)	3.34	2.49
Average cost of purchased power (in cents per net KWH)	4.54	4.08

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AND RESULTS OF OPERATIONS (Continued)

Fuel

In the first quarter 2022, fuel expense was $132 million compared to $106 million for the corresponding period in 2021. The increase was due to a 36.9% increase in the average cost of natural gas per KWH generated and an 18.0% increase in the average cost of coal per KWHs generated, partially offset by a 16.9% decrease in the volume of KWHs generated by coal and a 6.1% decrease in the volume of KWHs generated by natural gas.

Other Operations and Maintenance Expenses

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$8	11.8

In the first quarter 2022, other operations and maintenance expenses were $76 million compared to $68 million for the corresponding period in 2021. The increase was primarily due to increases of $4 million associated with the Kemper County energy facility (primarily related to additional dismantlement activities and lower salvage proceeds in 2022 as compared to 2021) and $3 million in distribution and transmission operations and maintenance activities.

Southern Power

Net Income Attributable to Southern Power

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(25)	(25.8)

Net income attributable to Southern Power in the first quarter 2022 was $72 million compared to $97 million for the corresponding period in 2021. The decrease was primarily due to gains from the contributions of wind turbine equipment to various equity method investments in the first quarter 2021.

Operating Revenues

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$99	22.5

Total operating revenues include PPA capacity revenues, which are derived primarily from long-term contracts involving natural gas facilities, and PPA energy revenues from Southern Power's generation facilities. To the extent Southern Power has capacity not contracted under a PPA, it may sell power into an accessible wholesale market, or, to the extent those generation assets are part of the FERC-approved IIC, it may sell power into the Southern Company power pool.

Natural Gas Capacity and Energy Revenue

Capacity revenues generally represent the greatest contribution to operating income and are designed to provide recovery of fixed costs plus a return on investment.

Energy is generally sold at variable cost or is indexed to published natural gas indices. Energy revenues will vary depending on the energy demand of Southern Power's customers and their generation capacity, as well as the market prices of wholesale energy compared to the cost of Southern Power's energy. Energy revenues also include fees for support services, fuel storage, and unit start charges. Increases and decreases in energy revenues under PPAs that are driven by fuel or purchased power prices are accompanied by an increase or decrease in fuel and purchased power costs and do not have a significant impact on net income.

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AND RESULTS OF OPERATIONS (Continued)

Solar and Wind Energy Revenue

Southern Power's energy sales from solar and wind generating facilities are predominantly through long-term PPAs that do not have capacity revenue. Customers either purchase the energy output of a dedicated renewable facility through an energy charge or pay a fixed price related to the energy generated from the respective facility and sold to the grid. As a result, Southern Power's ability to recover fixed and variable operations and maintenance expenses is dependent upon the level of energy generated from these facilities, which can be impacted by weather conditions, equipment performance, transmission constraints, and other factors.

See FUTURE EARNINGS POTENTIAL – "Southern Power's Power Sales Agreements" in Item 7 of the Form 10-K for additional information regarding Southern Power's PPAs.

Operating Revenues Details

Details of Southern Power's operating revenues were as follows:

	First Quarter 2022		First Quarter 2021
	(in millions)
PPA capacity revenues	$	102	$	96
PPA energy revenues	345		245
Total PPA revenues	447		341
Non-PPA revenues	84		95
Other revenues	8		4
Total operating revenues	$	539	$	440

In the first quarter 2022, total operating revenues were $539 million, reflecting a $99 million, or 23%, increase from the corresponding period in 2021. The increase in operating revenues was primarily due to the following:

•PPA capacity revenues increased $6 million, or 6%, primarily due to new natural gas PPAs and increased capacity sales under existing natural gas PPAs, partially offset by the contractual expiration of natural gas PPAs.

•PPA energy revenues increased $100 million, or 41%, primarily due to a $59 million increase in sales under existing natural gas PPAs resulting from a $37 million increase in the price of fuel and purchased power and a $22 million increase in the volume of KWHs sold. Also contributing to the increase was a $47 million increase in sales associated with new natural gas PPAs, partially offset by a $13 million decrease due to the contractual expiration of natural gas PPAs.

•Non-PPA revenues decreased $11 million, or 12%, primarily due to a $12 million decrease in the volume of KWHs sold through short-term sales.

Fuel and Purchased Power Expenses

Details of Southern Power's generation and purchased power were as follows:

	First Quarter 2022	First Quarter 2021
	(in billions of KWHs)
Generation	11.0	9.4
Purchased power	0.5	0.6
Total generation and purchased power	11.5	10.0
Total generation and purchased power (excluding solar, wind, fuel cells, and tolling agreements)	6.9	6.1

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Southern Power's PPAs for natural gas generation generally provide that the purchasers are responsible for either procuring the fuel (tolling agreements) or reimbursing Southern Power for substantially all of the cost of fuel relating to the energy delivered under such PPAs. Consequently, changes in such fuel costs are generally accompanied by a corresponding change in related fuel revenues and do not have a significant impact on net income. Southern Power is responsible for the cost of fuel for generating units that are not covered under PPAs. Power from these generating units is sold into the wholesale market or into the Southern Company power pool for capacity owned directly by Southern Power.

Purchased power expenses will vary depending on demand, availability, and the cost of generating resources throughout the Southern Company system and other contract resources. Load requirements are submitted to the Southern Company power pool on an hourly basis and are fulfilled with the lowest cost alternative, whether that is generation owned by Southern Power, an affiliate company, or external parties. Such purchased power costs are generally recovered through PPA revenues.

Details of Southern Power's fuel and purchased power expenses were as follows:

	First Quarter 2022 vs. First Quarter 2021
	(change in millions)		(% change)
Fuel	$	91	64.5
Purchased power	1		5.0
Total fuel and purchased power expenses	$	92

In the first quarter 2022, total fuel and purchased power expenses increased $92 million, or 57%, compared to the corresponding period in 2021 primarily due to a $68 million increase in the average cost of fuel per KWH generated and a $23 million increase associated with the volume of KWHs generated.

Gain on Dispositions, Net

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(37)	(94.9)

In the first quarter 2022, gain on dispositions, net was $2 million compared to $39 million for the corresponding period in 2021. The decrease primarily resulted from gains associated with contributions of wind turbine equipment to various equity method investments in the first quarter 2021. See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K and Note (E) to the Condensed Financial Statements under "Southern Power" herein for additional information.

Net Loss Attributable to Noncontrolling Interests

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$13	40.6

In the first quarter 2022, net loss attributable to noncontrolling interests was $45 million compared to $32 million for the corresponding period in 2021. The increased loss was primarily due to loss allocations to the partners in the Garland and Tranquillity battery energy storage facilities and higher HLBV loss allocations to wind tax equity partners, including new partnerships entered into during 2021. The increased loss allocations were partially offset by higher income allocations to solar equity partners.

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AND RESULTS OF OPERATIONS (Continued)

Southern Company Gas

Operating Metrics

Southern Company Gas continues to focus on several operating metrics, including Heating Degree Days, customer count, and volumes of natural gas sold.

Southern Company Gas measures weather and the effect on its business using Heating Degree Days. Generally, increased Heating Degree Days result in higher demand for natural gas on Southern Company Gas' distribution system. Southern Company Gas has various regulatory mechanisms, such as weather and revenue normalization and straight-fixed-variable rate design, which limit its exposure to weather changes within typical ranges in each of its utility's respective service territory. Southern Company Gas also utilizes weather hedges to limit the negative income impacts in the event of warmer-than-normal weather.

The number of customers served by gas distribution operations and gas marketing services can be impacted by natural gas prices, economic conditions, and competition from alternative fuels. Gas distribution operations and gas marketing services' customers are primarily located in Georgia and Illinois.

Southern Company Gas' natural gas volume metrics for gas distribution operations and gas marketing services illustrate the effects of weather and customer demand for natural gas.

Seasonality of Results

During the Heating Season, natural gas usage and operating revenues are generally higher as more customers are connected to the gas distribution systems and natural gas usage is higher in periods of colder weather. Prior to the sale of Sequent on July 1, 2021, wholesale gas services' operating revenues occasionally were impacted due to peak usage by power generators in response to summer energy demands. Southern Company Gas' base operating expenses, excluding cost of natural gas, bad debt expense, and certain incentive compensation costs, are incurred relatively evenly throughout the year. Seasonality also affects the comparison of certain balance sheet items across quarters, including receivables, unbilled revenues, natural gas for sale, and notes payable. However, these items are comparable when reviewing Southern Company Gas' annual results. Thus, Southern Company Gas' operating results for the interim periods presented are not necessarily indicative of annual results and can vary significantly from quarter to quarter.

Net Income

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(79)	(19.8)

In the first quarter 2022, net income was $319 million compared to $398 million for the corresponding period in 2021. The first quarter 2021 results include $126 million of net income from Sequent, which was sold on July 1, 2021. Net income increased $31 million at gas distribution operations primarily due to base rate increases and continued investment in infrastructure replacement and $10 million at gas marketing services primarily related to higher commodity prices and higher sales to commercial customers. See Notes 2 and 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Natural Gas Revenues, including Alternative Revenue Programs

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$364	21.5

In the first quarter 2022, natural gas revenues, including alternative revenue programs, were $2.1 billion compared to $1.7 billion for the corresponding period in 2021.

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Details of the changes in natural gas revenues, including alternative revenue programs, were as follows:

	First Quarter 2022
	(in millions)		(% change)
Natural gas revenues – prior year	$	1,694
Estimated change resulting from –
Infrastructure replacement programs and base rate changes	86		5.1	%
Gas costs and other cost recovery	544		32.1
Gas marketing services	18		1.1
Wholesale gas services	(297)		(17.5)
Other	13		0.7
Natural gas revenues – current year	$	2,058	21.5	%

Revenues from infrastructure replacement programs and base rate changes increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to rate increases at Atlanta Gas Light and Chattanooga Gas and continued investment in infrastructure replacement. See Note 2 to the financial statements under "Southern Company Gas – Rate Proceedings" in Item 8 of the Form 10-K for additional information.

Revenues associated with gas costs and other cost recovery increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher volumes of natural gas sold and higher natural gas cost recovery. See "Cost of Natural Gas" herein for additional information. Revenue impacts from weather and customer growth are described further below.

Revenues from gas marketing services increased in the first quarter 2022 compared to the corresponding period in 2021 primarily due to higher commodity prices and higher sales to commercial customers.

The change in revenues related to wholesale gas services was due to the sale of Sequent on July 1, 2021. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Southern Company Gas' natural gas distribution utilities have various regulatory mechanisms that limit their exposure to weather changes. Southern Company Gas also uses hedges for any remaining exposure to warmer-than-normal weather in Illinois for gas distribution operations and in Illinois and Georgia for gas marketing services; therefore, weather typically does not have a significant net income impact. The following table presents Heating Degree Days information for Illinois and Georgia, the primary locations where Southern Company Gas' operations are impacted by weather.

	First Quarter			2022 vs. normal		2022 vs. 2021
	Normal(*)	2022	2021	colder (warmer)		colder (warmer)
	(in thousands)
Illinois	2,999	3,007	2,947	0.3	%	2.0	%
Georgia	1,302	1,251	1,254	(3.9)	%	(0.2)	%

(*)Normal represents the 10-year average from January 1, 2012 through March 31, 2021 for Illinois at Chicago Midway International Airport and for Georgia at Atlanta Hartsfield-Jackson International Airport, based on information obtained from the National Oceanic and Atmospheric Administration, National Climatic Data Center.

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The following table provides the number of customers served by Southern Company Gas at March 31, 2022 and 2021:

	March 31,
	2022		2021		2022 vs. 2021
	(in thousands, except market share %)				(% change)
Gas distribution operations	4,358		4,335		0.5	%
Gas marketing services
Energy customers(*)	598		667		(10.3)	%
Market share of energy customers in Georgia	28.7	%	28.9	%

(*)Gas marketing services' customers are primarily located in Georgia and Illinois. March 31, 2021 also includes approximately 50,000 customers in Ohio contracted through an annual auction process to serve for 12 months beginning April 1, 2020.

Southern Company Gas anticipates customer growth and uses a variety of targeted marketing programs to attract new customers and to retain existing customers.

Cost of Natural Gas

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$512	87.8

Excluding Atlanta Gas Light, which does not sell natural gas to end-use customers, natural gas distribution rates include provisions to adjust billings for fluctuations in natural gas costs. Therefore, gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas and do not affect net income from gas distribution operations. Cost of natural gas at gas distribution operations represented 90% of the total cost of natural gas in the first quarter 2022. See MANAGEMENT'S DISCUSSION AND ANALYSIS – RESULTS OF OPERATIONS – "Southern Company Gas – Cost of Natural Gas" in Item 7 of the Form 10-K and "Natural Gas Revenues, including Alternative Revenue Programs" herein for additional information.

In the first quarter 2022, cost of natural gas was $1.1 billion compared to $583 million for the corresponding period in 2021. The increase reflects higher gas cost recovery as a result of an 83.9% increase in natural gas prices in the first quarter 2022 compared to the corresponding period in 2021.

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The following table details the volumes of natural gas sold during all periods presented.

	First Quarter		2022 vs. 2021
	2022	2021
Gas distribution operations (mmBtu in millions)
Firm	304	288	5.6	%
Interruptible	25	26	(3.8)
Total	329	314	4.8	%
Wholesale gas services (mmBtu in millions/day)
Daily physical sales(*)	—	7.1	(100.0)	%
Gas marketing services (mmBtu in millions)
Firm:
Georgia	16	19	(15.8)	%
Illinois	3	4	(25.0)
Other	4	6	(33.3)
Interruptible large commercial and industrial	4	4	—
Total	27	33	(18.2)	%

(*)As a result of the sale of Sequent, wholesale gas services had no sales in the first quarter 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Other Operations and Maintenance Expenses

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$6	2.0

In the first quarter 2022, other operations and maintenance expenses were $305 million compared to $299 million for the corresponding period in 2021. Excluding $48 million of expenses related to Sequent in 2021, other operations and maintenance expenses increased approximately $54 million. The increase was primarily due to increases of $18 million in compensation and benefit expenses, $16 million in expenses passed through directly to customers primarily related to bad debt at distribution operations, and $6 million in customer account expenses.

Depreciation and Amortization

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$7	5.4

In the first quarter 2022, depreciation and amortization was $137 million compared to $130 million for the corresponding period in 2021. The increase was primarily due to continued infrastructure investments at the natural gas distribution utilities.

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Taxes Other Than Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$19	23.5

In the first quarter 2022, taxes other than income taxes were $100 million compared to $81 million for the corresponding period in 2021. The increase primarily reflects an increase in revenue tax expenses as a result of higher natural gas revenues at Nicor Gas. These revenue tax expenses are passed directly to customers and have no impact on net income.

Other Income (Expense), Net

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$79	125.4

In the first quarter 2022, other income (expense), net was $16 million of income compared to $63 million of expense for the corresponding period in 2021. The change was largely due to charitable contributions of $75 million in the first quarter 2021.

Income Taxes

First Quarter 2022 vs. First Quarter 2021
(change in millions)	(% change)
$(24)	(19.8)

In the first quarter 2022, income taxes were $97 million compared to $121 million for the corresponding period in 2021. The decrease was primarily due to a decrease of $40 million at wholesale gas services including Sequent, which was sold on July 1, 2021, partially offset by higher pre-tax earnings from the other segments.

Segment Information

Operating revenues, operating expenses, and net income (loss) for each segment are provided in the table below. See Note (L) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.

	First Quarter 2022						First Quarter 2021
	Operating Revenues		Operating Expenses		Net Income (Loss)		Operating Revenues		Operating Expenses		Net Income (Loss)
	(in millions)						(in millions)
Gas distribution operations	$	1,803	$	1,475	$	214	$	1,200	$	913	$	183
Gas pipeline investments	8		3		29		8		3		29
Wholesale gas services(*)	—		—		—		298		56		126
Gas marketing services	243		150		66		195		120		56
All other	16		21		10		7		15		4
Intercompany eliminations	(12)		(12)		—		(14)		(14)		—
Consolidated	$	2,058	$	1,637	$	319	$	1,694	$	1,093	$	398

(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the first quarter 2022. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Gas Distribution Operations

Gas distribution operations is the largest component of Southern Company Gas' business and is subject to regulation and oversight by regulatory agencies in each of the states it serves. These agencies approve natural gas rates designed to provide Southern Company Gas with the opportunity to generate revenues to recover the cost of natural gas delivered to its customers and its fixed and variable costs, including depreciation, interest expense, operations and maintenance, taxes, and overhead costs, and to earn a reasonable return on its investments.

With the exception of Atlanta Gas Light, Southern Company Gas' second largest utility that operates in a deregulated natural gas market and has a straight-fixed-variable rate design that minimizes the variability of its revenues based on consumption, the earnings of the natural gas distribution utilities can be affected by customer consumption patterns that are a function of weather conditions, price levels for natural gas, and general economic conditions that may impact customers' ability to pay for natural gas consumed. Southern Company Gas has various regulatory and other mechanisms, such as weather and revenue normalization mechanisms and weather derivative instruments, that limit its exposure to changes in customer consumption, including weather changes within typical ranges in its natural gas distribution utilities' service territories. See Note 2 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

In the first quarter 2022, net income increased $31 million, or 16.9%, when compared to the corresponding period in 2021, as described further below:

•Operating revenues increased $603 million primarily due to higher gas cost recovery, rate increases, and continued investment in infrastructure replacement. Gas costs recovered through natural gas revenues generally equal the amount expensed in cost of natural gas.

•Operating expenses increased $562 million primarily due to a $479 million increase in the cost of gas as a result of higher natural gas prices and higher volumes sold compared to 2021, as well as higher compensation expenses and depreciation resulting from additional assets placed in service. The increase in operating expenses also includes higher costs passed through directly to customers, primarily related to bad debt expenses and revenue taxes.

•Income taxes increased $12 million primarily due to higher pre-tax earnings.

Gas Pipeline Investments

Gas pipeline investments consists primarily of joint ventures in natural gas pipeline investments including SNG, Dalton Pipeline, and PennEast Pipeline. See Note (E) to the Condensed Financial Statements under "Southern Company Gas" herein for additional information.

Gas Marketing Services

Gas marketing services provides energy-related products and services to natural gas markets and participants in customer choice programs that were approved in various states to increase competition. These programs allow customers to choose their natural gas supplier while the local distribution utility continues to provide distribution and transportation services. Gas marketing services is weather sensitive and uses a variety of hedging strategies, such as weather derivative instruments and other risk management tools, to partially mitigate potential weather impacts.

In the first quarter 2022, net income increased $10 million, or 17.9%, when compared to the corresponding period in 2021. The increase was primarily due to a $48 million increase in operating revenues as a result of higher commodity prices and higher sales to commercial customers, partially offset by a $30 million increase in operating expenses primarily due to higher cost of natural gas and an increase of $8 million in income taxes as a result of higher pre-tax earnings.

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All Other

All other includes natural gas storage businesses, a renewable natural gas business, AGL Services Company, and Southern Company Gas Capital, as well as various corporate operating expenses that are not allocated to the reportable segments and interest income (expense) associated with affiliate financing arrangements.

In the first quarter 2022, net income increased $6 million, or 150%, when compared to the corresponding period in 2021. Operating revenues increased $9 million primarily related to higher demand fees and favorable hedge gains at the natural gas storage businesses and higher sales from the renewable natural gas business, partially offset by a $6 million increase in operating expenses primarily due to higher cost of natural gas.

FUTURE EARNINGS POTENTIAL

Each Registrant's results of operations are not necessarily indicative of its future earnings potential. The level of the Registrants' future earnings depends on numerous factors that affect the opportunities, challenges, and risks of the Registrants' primary businesses of selling electricity and/or distributing natural gas, as described further herein.

For the traditional electric operating companies, these factors include the ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs during a time of increasing costs, including those related to projected long-term demand growth, stringent environmental standards, including CCR rules, safety, system reliability and resiliency, fuel, restoration following major storms, and capital expenditures, including constructing new electric generating plants and expanding and improving the transmission and distribution systems; continued customer growth; and the trend of reduced electricity usage per customer, especially in residential and commercial markets. For Georgia Power, completing construction of Plant Vogtle Units 3 and 4 and the related cost recovery proceedings is another major factor.

Earnings in the electricity business will also depend upon maintaining and growing sales, considering, among other things, the adoption and/or penetration rates of increasingly energy-efficient technologies and increasing volumes of electronic commerce transactions, which could contribute to a net reduction in customer usage.

Global and U.S. economic conditions have been significantly affected by a series of demand and supply shocks that caused a global and national economic recession in 2020. Most prominently, the COVID-19 pandemic has negatively impacted global supply chains and business operations as suppliers continue to experience difficulties keeping up with strong demand for factory goods, which is being driven by low business inventories. In addition, rising inflation in 2021 and 2022 has resulted in increasing costs for many goods and services. As a result of persistently high inflation, interest rates have been on the rise and are expected to continue rising in the near term. The combination of rising inoculation rates in the U.S. population and the federal COVID-19 relief package contributed to increased economic recovery in 2021 and has sustained the current economic expansion through the first quarter 2022; however, fiscal support of business and personal incomes is declining. Russia's invasion of Ukraine has intensified supply chain disruptions and heightened uncertainty surrounding the near-term outlook for the broader economy and the economy within the Southern Company system's service territory. The drivers, speed, and depth of the 2020 economic contraction were unprecedented and have reduced energy demand across the Southern Company system's service territory, primarily in the commercial and industrial classes. Retail electric revenues attributable to changes in sales increased in the first quarter 2022 when compared to the corresponding period in 2021 primarily due to the normalization of economic activity; however, retail electric sales continued to be negatively impacted by the COVID-19 pandemic when compared to pre-pandemic trends. The impacts of new COVID-19 variants, responses to the COVID-19 pandemic by both customers and governments, inflation, rising interest rates, and the unresolved geopolitical tensions relating to Russia's invasion of Ukraine could significantly affect the sustainability of current economic growth. See RESULTS OF OPERATIONS herein for information on COVID-19-related impacts on energy demand in the Southern Company system's service territory during the first quarter 2022.

The level of future earnings for Southern Power's competitive wholesale electric business depends on numerous factors including the parameters of the wholesale market and the efficient operation of its wholesale generating assets; Southern Power's ability to execute its growth strategy through the development or acquisition of renewable

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facilities and other energy projects while containing costs; regulatory matters; customer creditworthiness; total electric generating capacity available in Southern Power's market areas; Southern Power's ability to successfully remarket capacity as current contracts expire; renewable portfolio standards; availability of federal and state ITCs and PTCs, which could be impacted by future tax legislation; transmission constraints; cost of generation from units within the Southern Company power pool; and operational limitations.

The level of future earnings for Southern Company Gas' primary business of distributing natural gas and its complementary businesses in the gas pipeline investments and gas marketing services sectors depends on numerous factors. These factors include the natural gas distribution utilities' ability to maintain constructive regulatory environments that allow for the timely recovery of prudently-incurred costs, including those related to projected long-term demand growth, safety, system reliability and resiliency, natural gas, and capital expenditures, including expanding and improving the natural gas distribution systems; the completion and subsequent operation of ongoing infrastructure and other construction projects; customer creditworthiness; certain policies to limit the use of natural gas, such as the potential across certain parts of the U.S. for state or municipal bans on the use of natural gas; and Southern Company Gas' ability to re-contract storage rates at favorable prices. The volatility of natural gas prices has an impact on Southern Company Gas' customer rates, its long-term competitive position against other energy sources, and the ability of Southern Company Gas' gas marketing services business to capture value from locational and seasonal spreads. Additionally, changes in commodity prices, primarily driven by tight gas supplies, geopolitical events, and diminished gas production, subject a portion of Southern Company Gas' operations to earnings variability and have recently resulted in higher natural gas prices. Additional economic factors may contribute to this environment. If current economic conditions continue to improve, the demand for natural gas may increase, which may cause natural gas prices to rise and drive higher volatility in the natural gas markets on a longer-term basis. Alternatively, a significant drop in oil and natural gas prices could lead to a consolidation of natural gas producers or reduced levels of natural gas production.

Earnings for both the electricity and natural gas businesses are subject to a variety of other factors. These factors include weather, competition, developing new and maintaining existing energy contracts and associated load requirements with wholesale customers, energy conservation practiced by customers, the use of alternative energy sources by customers, government incentives to reduce overall energy usage, the prices of electricity and natural gas, costs and availability of labor and materials in a time of rising costs and supply chain disruptions, and the price elasticity of demand. Demand for electricity and natural gas in the Registrants' service territories is primarily driven by the pace of economic growth or decline that may be affected by changes in regional and global economic conditions, which may impact future earnings.

As part of its ongoing effort to adapt to changing market conditions, Southern Company continues to evaluate and consider a wide array of potential business strategies. These strategies may include business combinations, partnerships, and acquisitions involving other utility or non-utility businesses or properties, disposition of, or the sale of interests in, certain assets or businesses, internal restructuring, or some combination thereof. Furthermore, Southern Company may engage in new business ventures that arise from competitive and regulatory changes in the utility industry. Pursuit of any of the above strategies, or any combination thereof, may significantly affect the business operations, risks, and financial condition of Southern Company. In addition, Southern Power and Southern Company Gas regularly consider and evaluate joint development arrangements as well as acquisitions and dispositions of businesses and assets as part of their business strategies. See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein for additional information.

For additional information relating to these issues, see RISK FACTORS in Item 1A and MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL in Item 7 of the Form 10-K.

Environmental Matters

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FUTURE EARNINGS POTENTIAL – "Environmental Matters" in Item 7 and Note 3 to the financial statements under "Environmental Remediation" in Item 8 of the Form 10-K, as well as Note (C) to the Condensed Financial Statements under "Environmental Remediation" herein, for additional information.

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Regulatory Matters

See Note 2 to the financial statements in Item 8 of the Form 10-K, OVERVIEW – "Recent Developments" herein, and Note (B) to the Condensed Financial Statements herein for a discussion of regulatory matters related to Alabama Power, Georgia Power, Mississippi Power, and Southern Company Gas, including items that could impact the applicable Registrants' future earnings, cash flows, and/or financial condition.

Construction Programs

The Subsidiary Registrants are engaged in continuous construction programs to accommodate existing and estimated future loads on their respective systems. The Southern Company system strategy continues to include developing and constructing new electric generating facilities, expanding and improving the electric transmission and electric and natural gas distribution systems, and undertaking projects to comply with environmental laws and regulations.

For the traditional electric operating companies, major generation construction projects are subject to state PSC approval in order to be included in retail rates. The largest construction project currently underway in the Southern Company system is Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information. Also see Note 2 to the financial statements under "Alabama Power – Certificates of Convenience and Necessity" in Item 8 of the Form 10-K for information regarding Alabama Power's construction of Plant Barry Unit 8.

See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for information about costs relating to Southern Power's construction of renewable energy facilities.

Southern Company Gas is engaged in various infrastructure improvement programs designed to update or expand the natural gas distribution systems of the natural gas distribution utilities to improve reliability and meet operational flexibility and growth. The natural gas distribution utilities recover their investment and a return associated with these infrastructure programs through their regulated rates. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Southern Company Gas" for additional information on Southern Company Gas' construction program.

See FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" herein for additional information regarding the Registrants' capital requirements for their construction programs.

General Litigation and Other Matters

The Registrants are involved in various matters being litigated and/or regulatory and other matters that could affect future earnings, cash flows, and/or financial condition. The ultimate outcome of such pending or potential litigation against each Registrant and any subsidiaries or regulatory and other matters cannot be determined at this time; however, for current proceedings and/or matters not specifically reported herein or in Notes (B) and (C) to the Condensed Financial Statements herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings and/or matters would have a material effect on such Registrant's financial statements. See Notes (B) and (C) to the Condensed Financial Statements for a discussion of various contingencies, including matters being litigated, regulatory matters, and other matters which may affect future earnings potential.

ACCOUNTING POLICIES

See MANAGEMENT'S DISCUSSION AND ANALYSIS – ACCOUNTING POLICIES in Item 7 of the Form 10-K for a complete discussion of the Registrants' critical accounting policies and estimates, as well as recently issued accounting standards.

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The Registrants prepare their financial statements in accordance with GAAP. Significant accounting policies are described in the notes to the financial statements in Item 8 of the Form 10-K. In the application of these policies, certain estimates are made that may have a material impact on the Registrants' results of operations and related disclosures. Different assumptions and measurements could produce estimates that are significantly different from those recorded in the financial statements.

FINANCIAL CONDITION AND LIQUIDITY

Overview

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Overview" in Item 7 of the Form 10-K for additional information. The financial condition of each Registrant remained stable at March 31, 2022. The Registrants intend to continue to monitor their access to short-term and long-term capital markets as well as their bank credit arrangements to meet future capital and liquidity needs. See "Cash Requirements," "Sources of Capital," and "Financing Activities" herein for additional information.

At the end of the first quarter 2022, the market price of Southern Company's common stock was $72.51 per share (based on the closing price as reported on the NYSE) and the book value was $26.63 per share, representing a market-to-book ratio of 272%, compared to $68.58, $26.30, and 261%, respectively, at the end of 2021. Southern Company's common stock dividend for the first quarter 2022 was $0.66 per share compared to $0.64 per share in the first quarter 2021.

Cash Requirements

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Cash Requirements" in Item 7 of the Form 10-K for a description of the Registrants' significant cash requirements.

The Registrants' significant cash requirements include estimated capital expenditures associated with their construction programs. The construction programs are subject to periodic review and revision, and actual construction costs may vary from these estimates because of numerous factors. These factors include: changes in business conditions; changes in load projections; changes in environmental laws and regulations; the outcome of any legal challenges to environmental rules; changes in electric generating plants, including unit retirements and replacements and adding or changing fuel sources at existing electric generating units, to meet regulatory requirements; changes in FERC rules and regulations; state regulatory agency approvals; changes in the expected environmental compliance program; changes in legislation and/or regulation; the cost, availability, and efficiency of construction labor, equipment, and materials; project scope and design changes; abnormal weather; delays in construction due to judicial or regulatory action; storm impacts; and the cost of capital. The continued impacts of the COVID-19 pandemic could also impair the ability to develop, construct, and operate facilities, as discussed further in Item 1A of the Form 10-K. In addition, there can be no assurance that costs related to capital expenditures and AROs will be fully recovered. Additionally, expenditures associated with Southern Power's planned acquisitions may vary due to market opportunities and the execution of its growth strategy. See Note 15 to the financial statements in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements herein under "Southern Power" for additional information regarding Southern Power's plant acquisitions and construction projects.

The construction program of Georgia Power includes Plant Vogtle Units 3 and 4, which includes components based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale and which may be subject to additional revised cost estimates during construction. See Note 2 to the financial statements in Item 8 of the Form 10-K and Note (B) to the Condensed Financial Statements herein under "Georgia Power – Nuclear Construction" for information regarding Plant Vogtle Units 3 and 4 and additional factors that may impact construction expenditures.

Long-term debt maturities and the interest payable on long-term debt each represent a significant cash requirement for the Registrants. See "Financing Activities" herein for information on changes in the Registrants' long-term debt balances since December 31, 2021.

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AND RESULTS OF OPERATIONS (Continued)

Sources of Capital

See MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Sources of Capital" in Item 7 of the Form 10-K for additional information. Southern Company intends to meet its future capital needs through operating cash flows, borrowings from financial institutions, and debt and equity issuances. Equity capital can be provided from any combination of Southern Company's stock plans, private placements, or public offerings. With the exception of the settlement later in 2022 of stock purchase contracts associated with its equity units, Southern Company does not expect to issue any equity in the capital markets through 2026, but may issue equity through its stock plans during this time. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K for additional information.

The Subsidiary Registrants plan to obtain the funds to meet their future capital needs from sources similar to those they used in the past, which were primarily from operating cash flows, external securities issuances, borrowings from financial institutions, and equity contributions from Southern Company. In addition, Southern Power plans to utilize tax equity partnership contributions (as discussed further herein).

The amount, type, and timing of any financings in 2022, as well as in subsequent years, will be contingent on investment opportunities and the Registrants' capital requirements and will depend upon prevailing market conditions, regulatory approvals (for certain of the Subsidiary Registrants), and other factors. See "Cash Requirements" and "Financing Activities" herein for additional information.

Southern Power utilizes tax equity partnerships as one of its financing sources, where the tax partner takes significantly all of the federal tax benefits. These tax equity partnerships are consolidated in Southern Power's financial statements and are accounted for using HLBV methodology to allocate partnership gains and losses. During the first quarter 2022, Southern Power obtained tax equity funding for existing tax equity partnerships totaling $51 million. See Note 1 to the financial statements under "General" in Item 8 of the Form 10-K and Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

By regulation, Nicor Gas is restricted, to the extent of its retained earnings balance, in the amount it can dividend or loan to affiliates and is not permitted to make money pool loans to affiliates. At March 31, 2022, the amount of subsidiary retained earnings restricted to dividend totaled $1.4 billion. This restriction did not impact Southern Company Gas' ability to meet its cash obligations, nor does management expect such restriction to materially impact Southern Company Gas' ability to meet its currently anticipated cash obligations.

Certain Registrants' current liabilities frequently exceed their current assets because of long-term debt maturities and the periodic use of short-term debt as a funding source, as well as significant seasonal fluctuations in cash needs. The Registrants generally plan to refinance long-term debt as it matures. The following table shows the amount by which current liabilities exceeded current assets at March 31, 2022 for the applicable Registrants:

At March 31, 2022	Southern Company		Georgia Power		Southern Power		Southern Company Gas
	(in millions)
Current liabilities in excess of current assets	$	1,137	$	1,764	$	235	$	186

The Registrants believe the need for working capital can be adequately met by utilizing operating cash flows, as well as commercial paper, lines of credit, and short-term bank notes, as market conditions permit. In addition, under certain circumstances, the Subsidiary Registrants may utilize equity contributions and/or loans from Southern Company.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Bank Credit Arrangements

At March 31, 2022, the Registrants' unused committed credit arrangements with banks were as follows:

At March 31, 2022	Southern Company parent		Alabama Power		Georgia Power		Mississippi Power		Southern  Power(a)		Southern Company Gas(b)		SEGCO		Southern Company
	(in millions)
Unused committed credit	$	1,998	$	1,250	$	1,726	$	255	$	568	$	1,747	$	30	$	7,574

(a)At March 31, 2022, Southern Power also had two continuing letters of credit facilities for standby letters of credit, of which $30 million was unused. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)Includes $1.047 billion and $700 million at Southern Company Gas Capital and Nicor Gas, respectively.

Subject to applicable market conditions, the Registrants, Nicor Gas, and SEGCO expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, the Registrants, Nicor Gas, and SEGCO may extend the maturity dates and/or increase or decrease the lending commitments thereunder.

A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at March 31, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at March 31, 2022, Georgia Power had approximately $330 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

See Note 8 to the financial statements in Item 8 of the Form 10-K and Note (F) to the Condensed Financial Statements herein under "Bank Credit Arrangements" for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Short-term Borrowings

The Registrants, Nicor Gas, and SEGCO make short-term borrowings primarily through commercial paper programs that have the liquidity support of the committed bank credit arrangements described above. Southern Power's subsidiaries are not issuers or obligors under its commercial paper program. Commercial paper and short-term bank term loans are included in notes payable in the balance sheets. Details of the Registrants' short-term borrowings were as follows:

	Short-term Debt at March 31, 2022				Short-term Debt During the Period(*)
	Amount Outstanding		Weighted Average Interest Rate		Average Amount Outstanding		Weighted Average Interest Rate		Maximum Amount Outstanding
	(in millions)				(in millions)				(in millions)
Southern Company	$	2,330	0.9	%	$	1,878	0.5	%	$	2,894
Alabama Power	—		—		4		0.6		100
Georgia Power	860		0.9		290		0.7		900
Mississippi Power	25		1.5		10		0.8		71
Southern Power	208		0.9		164		0.4		220
Southern Company Gas:
Southern Company Gas Capital	$	259	0.9	%	$	312	0.4	%	$	379
Nicor Gas	273		0.8		551		0.5		830
Southern Company Gas Total	$	532	0.8	%	$	863	0.5	%

(*)Average and maximum amounts are based upon daily balances during the three-month period ended March 31, 2022.

Analysis of Cash Flows

Net cash flows provided from (used for) operating, investing, and financing activities for the three months ended March 31, 2022 and 2021 are presented in the following table:

Net cash provided from (used for):	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating activities	$	1,592	$	154	$	361	$	(16)	$	117	$	1,024
Investing activities	(1,555)		(365)		(809)		(68)		(37)		(271)
Financing activities	(193)		504		441		32		(76)		(768)
Three Months Ended March 31, 2021
Operating activities	$	1,242	$	214	$	489	$	(38)	$	187	$	550
Investing activities	(2,243)		(466)		(913)		(67)		(504)		(308)
Financing activities	1,734		341		444		90		478		50

Fluctuations in cash flows from financing activities vary from year to year based on capital needs and the maturity or redemption of securities.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Company

Net cash provided from operating activities increased $350 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery at the natural gas distribution utilities and the timing of vendor payments, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to the Subsidiary Registrants' construction programs.

The net cash used for financing activities for the three months ended March 31, 2022 was primarily related to common stock dividend payments and net redemptions of long-term debt, largely offset by an increase in short-term debt.

Alabama Power

Net cash provided from operating activities decreased $60 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of customer receivable collections, decreased fuel cost recovery, and the timing of fuel stock purchases, partially offset by the timing of vendor payments.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions.

The net cash provided from financing activities for the three months ended March 31, 2022 was primarily related to capital contributions from Southern Company and the net issuance of long-term debt, partially offset by common stock dividend payments.

Georgia Power

Net cash provided from operating activities decreased $128 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of customer receivable collections and decreased fuel cost recovery, partially offset by the timing of vendor payments.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions, including a total of approximately $240 million related to the construction of Plant Vogtle Units 3 and 4. See Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information on construction of Plant Vogtle Units 3 and 4.

The net cash provided from financing activities for the three months ended March 31, 2022 was primarily related to an increase in short-term borrowings and capital contributions from Southern Company, partially offset by common stock dividend payments and the redemption of senior notes.

Mississippi Power

Net cash used for operating activities decreased $22 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to gross property additions.

The net cash provided from financing activities for the three months ended March 31, 2022 was primarily related to capital contributions from Southern Company and an increase in short-term borrowings, partially offset by common stock dividend payments.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Power

Net cash provided from operating activities decreased $70 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to the timing of vendor payments and customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to construction payments. See Note (K) to the Condensed Financial Statements under "Southern Power" herein for additional information.

The net cash used for financing activities for the three months ended March 31, 2022 was primarily related to common stock dividend payments and a net capital distribution to noncontrolling interests.

Southern Company Gas

Net cash provided from operating activities increased $474 million for the three months ended March 31, 2022 as compared to the corresponding period in 2021 primarily due to increased natural gas cost recovery, partially offset by the timing of customer receivable collections.

The net cash used for investing activities for the three months ended March 31, 2022 was primarily related to construction of transportation and distribution assets recovered through base rates and infrastructure investment recovered through replacement programs at gas distribution operations.

The net cash used for financing activities for the three months ended March 31, 2022 was primarily related to net repayments of short-term debt and common stock dividend payments, partially offset by capital contributions from Southern Company.

Significant Balance Sheet Changes

Southern Company

Significant balance sheet changes for the three months ended March 31, 2022 included:

•an increase of $0.9 billion in notes payable due to an increase in short-term bank debt and commercial paper borrowings;

•an increase of $0.7 billion in total property, plant, and equipment primarily related to the Subsidiary Registrants' construction programs;

•increases of $0.6 billion in accumulated deferred income taxes and $0.4 billion in prepaid expenses primarily related to the expected utilization of ITCs in 2022;

•a decrease of $0.5 billion in accrued compensation due to the timing of payments; and

•a decrease of $0.5 billion in long-term debt (including securities due within one year) primarily due to the redemption of senior notes.

See "Financing Activities" herein and Note (G) to the Condensed Financial Statements herein for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Alabama Power

Significant balance sheet changes for the three months ended March 31, 2022 included:

•an increase of $719 million in common stockholder's equity primarily due to capital contributions from Southern Company;

•an increase of $293 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Alabama Power" herein;

•an increase of $161 million in total property, plant, and equipment primarily related to construction of distribution and transmission facilities, construction of Plant Barry Unit 8, and the installation of equipment to comply with environmental standards; and

•an increase of $145 million in long-term debt (including securities due within one year) primarily due to a net increase in outstanding senior notes.

See "Financing Activities – Alabama Power" herein for additional information.

Georgia Power

Significant balance sheet changes for the three months ended March 31, 2022 included:

•an increase of $860 million in notes payable due to an increase in short-term bank debt and commercial paper borrowings;

•an increase of $499 million in total property, plant, and equipment primarily related to the construction of generation, transmission, and distribution facilities, including $303 million for Plant Vogtle Units 3 and 4;

•a decrease of $421 million in long-term debt (including securities due within one year) primarily due to the redemption of senior notes; and

•an increase of $415 million in common stockholder's equity primarily due to capital contributions from Southern Company.

See "Financing Activities – Georgia Power" herein and Note (B) to the Condensed Financial Statements under "Georgia Power – Nuclear Construction" herein for additional information.

Mississippi Power

Significant balance sheet changes for the three months ended March 31, 2022 included:

•increases of $66 million in assets from risk management activities and $61 million in other regulatory liabilities, current primarily due to unrealized gains on short-term energy-related derivatives;

•a decrease of $64 million in accrued taxes primarily due to the payment of ad valorem taxes; and

•a decrease of $52 million in cash and cash equivalents, as discussed further under "Analysis of Cash Flows – Mississippi Power" herein.

See Note (J) to the Condensed Financial Statements herein for additional information.

Southern Power

Significant balance sheet changes for the three months ended March 31, 2022 included increases of $441 million in prepaid income taxes and $446 million in accumulated deferred income tax liabilities primarily related to the expected utilization of ITCs in 2022. See Note (G) to the Condensed Financial Statements herein for additional information.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Southern Company Gas

Significant balance sheet changes for the three months ended March 31, 2022 included:

•a decrease of $677 million in notes payable due to repayments of short-term debt and commercial paper borrowings;

•an increase of $259 million in common stockholder's equity related to net income and capital contributions from Southern Company, partially offset by dividends paid to Southern Company;

•a decrease of $241 million in natural gas for sale primarily due to higher volumes of natural gas sold;

•an increase of $209 million in temporary LIFO liquidation due to use of stored natural gas;

•a decrease of $181 million in other regulatory assets, deferred primarily due to a $163 million reduction in natural gas cost under recovery;

•an increase of $147 million in total property, plant, and equipment primarily related to the construction of transportation and distribution assets recovered through base rates and infrastructure investment recovered through replacement programs; and

•an increase of $141 million in customer accounts receivable due to the timing of collections.

See "Financing Activities – Southern Company Gas" herein and Note (B) to the Condensed Financial Statements herein for additional information.

Financing Activities

The following table outlines the Registrants' long-term debt financing activities for the first three months of 2022:

			Maturities and Redemptions
Company	Senior Note Issuances		Senior Notes		Other Long-Term Debt(*)
	(in millions)
Alabama Power	$	700	$	550	$	—
Georgia Power	—		400		24
Other	—		—		3
Southern Company	$	700	$	950	$	27

(*)Includes reductions in finance lease obligations resulting from cash payments under finance leases and, for Georgia Power, principal amortization payments totaling $24 million for FFB borrowings. See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for additional information.

Except as otherwise described herein, the Registrants used the proceeds of debt issuances for their redemptions and maturities shown in the table above, to repay short-term indebtedness, and for general corporate purposes, including working capital. The Subsidiary Registrants also used the proceeds for their construction programs.

In addition to any financings that may be necessary to meet capital requirements and contractual obligations, the Registrants plan to continue, when economically feasible, a program to retire higher-cost securities and replace these obligations with lower-cost capital if market conditions permit.

Southern Company

During the first quarter 2022, Southern Company issued approximately 2.6 million shares of common stock primarily through employee equity compensation plans and received proceeds of approximately $38 million.

In March 2022, Southern Company entered into a $400 million short-term floating rate bank loan bearing interest based on term SOFR.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

Alabama Power

In February 2022, Alabama Power redeemed all $550 million aggregate principal amount of its Series 2017A 2.45% Senior Notes due March 30, 2022.

In March 2022, Alabama Power issued $700 million aggregate principal amount of Series 2022A 3.05% Senior Notes due March 15, 2032.

Georgia Power

In January 2022, Georgia Power redeemed all $400 million aggregate principal amount of its Series 2012B 2.85% Senior Notes due May 15, 2022.

In February 2022, Georgia Power borrowed $250 million pursuant to a short-term uncommitted bank credit arrangement bearing interest at a rate agreed upon by Georgia Power and the bank from time to time and payable on demand, following specified notice by the bank.

In March 2022, Georgia Power entered into a $200 million short-term floating rate bank loan bearing interest based on term SOFR.

Subsequent to March 31, 2022, Georgia Power entered into an additional $200 million short-term floating rate bank loan bearing interest based on term SOFR.

Mississippi Power

In March 2022, Mississippi Power borrowed $20 million (short term) pursuant to its $125 million revolving credit arrangement bearing interest based on term SOFR.

Southern Company Gas

During the first quarter 2022, Nicor Gas repaid one of its three $100 million short-term floating rate bank loans entered into in March 2021. Nicor Gas repaid $50 million of one of the other loans and increased the borrowing amount under the other loan to $150 million. In addition, both loans were renewed and amended to extend the maturity dates and change the interest rate provisions so the loans bear interest based on term SOFR.

Subsequent to March 31, 2022, Atlanta Gas Light repaid at maturity $36 million aggregate principal amount of medium-term notes with a weighted average interest rate of 8.65%.

Credit Rating Risk

At March 31, 2022, the Registrants did not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade.

There are certain contracts that could require collateral, but not accelerated payment, in the event of a credit rating change of certain Registrants to BBB and/or Baa2 or below. These contracts are primarily for physical electricity and natural gas purchases and sales, fuel purchases, fuel transportation and storage, energy price risk management, transmission, interest rate management, and, for Georgia Power, construction of new generation at Plant Vogtle Units 3 and 4.

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MANAGEMENT'S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION

AND RESULTS OF OPERATIONS (Continued)

The maximum potential collateral requirements under these contracts at March 31, 2022 were as follows:

Credit Ratings	Southern Company(*)		Alabama Power		Georgia Power		Mississippi Power		Southern Power(*)		Southern Company Gas
	(in millions)
At BBB and/or Baa2	$	37	$	1	$	—	$	—	$	36	$	—
At BBB- and/or Baa3	427		2		61		1		365		—
At BB+ and/or Ba1 or below	1,946		405		924		305		1,202		5

(*)Southern Power has PPAs that could require collateral, but not accelerated payment, in the event of a downgrade of Southern Power's credit. The PPAs require credit assurances without stating a specific credit rating. The amount of collateral required would depend upon actual losses resulting from a credit downgrade. Southern Power had $105 million of cash collateral posted related to PPA requirements at March 31, 2022.

The amounts in the previous table for the traditional electric operating companies and Southern Power include certain agreements that could require collateral if either Alabama Power or Georgia Power has a credit rating change to below investment grade. Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. Additionally, a credit rating downgrade could impact the ability of the Registrants to access capital markets and would be likely to impact the cost at which they do so.

On February 22, 2022, Fitch downgraded the senior unsecured long-term debt rating of Georgia Power to BBB+ from A- with a stable outlook.

Also on February 22, 2022, Fitch revised the ratings outlook of Southern Company, Alabama Power, Southern Power, Nicor Gas, and SEGCO to negative from stable.

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Item 3. Quantitative and Qualitative Disclosures About Market Risk.

During the three months ended March 31, 2022, there were no material changes to Southern Company's, Alabama Power's, Georgia Power's, Mississippi Power's, Southern Power's, or Southern Company Gas' disclosures about market risk. For an in-depth discussion of each Registrant's market risks, see MANAGEMENT'S DISCUSSION AND ANALYSIS – FINANCIAL CONDITION AND LIQUIDITY – "Market Price Risk" in Item 7 of the Form 10-K and Note 1 to the financial statements under "Financial Instruments" and Notes 13 and 14 to the financial statements in Item 8 of the Form 10-K, as well as Notes (I) and (J) to the Condensed Financial Statements herein.

Item 4. Controls and Procedures.

(a)Evaluation of disclosure controls and procedures.

As of the end of the period covered by this Quarterly Report on Form 10-Q, Southern Company, Alabama Power, Georgia Power, Mississippi Power, Southern Power, and Southern Company Gas conducted separate evaluations under the supervision and with the participation of each company's management, including the Chief Executive Officer and the Chief Financial Officer, of the effectiveness of the design and operation of the disclosure controls and procedures (as defined in Sections 13a-15(e) and 15d-15(e) of the Securities Exchange Act of 1934, as amended). Based upon these evaluations, the Chief Executive Officer and the Chief Financial Officer, in each case, concluded that the disclosure controls and procedures are effective.

(b)    Changes in internal controls over financial reporting.

There have been no changes in Southern Power's or Southern Company Gas' internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended) during the first quarter 2022 that have materially affected or are reasonably likely to materially affect Southern Power's or Southern Company Gas' internal control over financial reporting.

In January 2022, Southern Company, Alabama Power, Georgia Power, and Mississippi Power implemented new financial accounting and reporting applications. As a result, there were certain changes to processes and procedures, which resulted in changes to Southern Company's, Alabama Power's, Georgia Power's, and Mississippi Power's internal control over financial reporting (as such term is defined in Rules 13a-15(f) and 15d-15(f) under the Securities Exchange Act of 1934, as amended). These changes include automation of certain previously manual controls. These changes in internal controls were not made in response to any identified internal control deficiency.

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PART II — OTHER INFORMATION

Item 1. Legal Proceedings.

See the Notes to the Condensed Financial Statements herein for information regarding certain legal and administrative proceedings in which the Registrants are involved. The Registrants' threshold for disclosing material environmental legal proceedings involving a governmental authority where potential monetary sanctions are involved is $1 million.

Item 1A. Risk Factors.

See RISK FACTORS in Item 1A of the Form 10-K for a discussion of the risk factors of the Registrants. There have been no material changes to these risk factors from those previously disclosed in the Form 10-K.

Item 6. Exhibits.

The exhibits below with an asterisk (*) preceding the exhibit number are filed herewith. The remaining exhibits have previously been filed with the SEC and are incorporated herein by reference. The exhibits marked with a pound sign (#) are management contracts or compensatory plans or arrangements.

		(4) Instruments Describing Rights of Security Holders, Including Indentures
		Alabama Power
		(b)	-	Sixty-Third Supplemental Indenture to Senior Note Indenture dated as of March 7, 2022, providing for the issuance of the Series 2022A 3.05% Senior Notes due March 15, 2032. (Designated in Form 8-K dated March 2, 2022, File No. 1-3164, as Exhibit 4.6)
		(10) Material Contracts
		Southern Company
#	*	(a)1	-	Form of Terms for Named Executive Officer Equity Awards Granted under The Southern Company 2021 Equity and Incentive Compensation Plan.
	*	(a)2	-	Fifth Amendment to The Southern Company Employee Savings Plan.
	*	(a)3	-	Sixth Amendment to The Southern Company Employee Savings Plan.
#	*	(a)4	-	Fourth Amendment to The Southern Company Deferred Compensation Plan.
#	*	(a)5	-	Eighth Amendment to The Southern Company Supplemental Benefit Plan.
		Alabama Power
#		(b)1	-	Form of Terms for Named Executive Officer Equity Awards Granted under The Southern Company 2021 Equity and Incentive Compensation Plan. See Exhibit 10(a)1 herein.
		(b)2	-	Fifth Amendment to The Southern Company Employee Savings Plan. See Exhibit 10(a)2 herein.
		(b)3	-	Sixth Amendment to The Southern Company Employee Savings Plan. See Exhibit 10(a)3 herein.
#		(b)4	-	Fourth Amendment to The Southern Company Deferred Compensation Plan. See Exhibit 10(a)4 herein.
#		(b)5	-	Eighth Amendment to The Southern Company Supplemental Benefit Plan. See Exhibit 10(a)5 herein.
		(24) Power of Attorney and Resolutions
		Southern Company
		(a)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 1-3526 as Exhibit 24(a)1.)

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	Alabama Power
	(b)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 1-3164 as Exhibit 24(b)1.)
	Georgia Power
	(c)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 1-6468 as Exhibit 24(c)1.)
	Mississippi Power
	(d)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 001-11229 as Exhibit 24(d)1.)
	Southern Power
	(e)	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 001-37803 as Exhibit 24(e)1.)
	Southern Company Gas
	(f)1	-	Power of Attorney and resolution. (Designated in the Form 10-K for the year ended December 31, 2021, File No. 1-14174 as Exhibit 24(f)1.)
	(31) Section 302 Certifications
	Southern Company
*	(a)1	-	Certificate of Southern Company's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(a)2	-	Certificate of Southern Company's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
	Alabama Power
*	(b)1	-	Certificate of Alabama Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(b)2	-	Certificate of Alabama Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
	Georgia Power
*	(c)1	-	Certificate of Georgia Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(c)2	-	Certificate of Georgia Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
	Mississippi Power
*	(d)1	-	Certificate of Mississippi Power's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(d)2	-	Certificate of Mississippi Power's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
	Southern Power
*	(e)1	-	Certificate of Southern Power Company's Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(e)2	-	Certificate of Southern Power Company's Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.

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	Southern Company Gas
*	(f)1	-	Certificate of Southern Company Gas' Chief Executive Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
*	(f)2	-	Certificate of Southern Company Gas' Chief Financial Officer required by Section 302 of the Sarbanes-Oxley Act of 2002.
	(32) Section 906 Certifications
	Southern Company
*	(a)	-	Certificate of Southern Company's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Alabama Power
*	(b)	-	Certificate of Alabama Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Georgia Power
*	(c)	-	Certificate of Georgia Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Mississippi Power
*	(d)	-	Certificate of Mississippi Power's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Southern Power
*	(e)	-	Certificate of Southern Power Company's Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	Southern Company Gas
*	(f)	-	Certificate of Southern Company Gas' Chief Executive Officer and Chief Financial Officer required by Section 906 of the Sarbanes-Oxley Act of 2002.
	(101) Interactive Data Files
*	INS	-	XBRL Instance Document – The instance document does not appear in the interactive data file because its XBRL tags are embedded within the inline XBRL document.
*	SCH	-	XBRL Taxonomy Extension Schema Document
*	CAL	-	XBRL Taxonomy Calculation Linkbase Document
*	DEF	-	XBRL Definition Linkbase Document
*	LAB	-	XBRL Taxonomy Label Linkbase Document
*	PRE	-	XBRL Taxonomy Presentation Linkbase Document
	(104) Cover Page Interactive Data File
*			Formatted as inline XBRL with applicable taxonomy extension information contained in Exhibits 101.

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THE SOUTHERN COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	THE SOUTHERN COMPANY
By	Thomas A. Fanning
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Daniel S. Tucker
	Executive Vice President and Chief Financial Officer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

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ALABAMA POWER COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	ALABAMA POWER COMPANY
By	Mark A. Crosswhite
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Philip C. Raymond
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

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GEORGIA POWER COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	GEORGIA POWER COMPANY
By	Christopher C. Womack
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Aaron P. Abramovitz
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

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    Table of Contents                                Index to Financial Statements

MISSISSIPPI POWER COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	MISSISSIPPI POWER COMPANY
By	Anthony L. Wilson
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	Moses H. Feagin
	Senior Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

135

    Table of Contents                                Index to Financial Statements

SOUTHERN POWER COMPANY

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	SOUTHERN POWER COMPANY
By	Christopher Cummiskey
	Chairman and Chief Executive Officer
	(Principal Executive Officer)
By	Elliott L. Spencer
	Senior Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

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SOUTHERN COMPANY GAS

SIGNATURES

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized. The signature of the undersigned company shall be deemed to relate only to matters having reference to such company and any subsidiaries thereof included in such company's report.

	SOUTHERN COMPANY GAS
By	Kimberly S. Greene
	Chairman, President, and Chief Executive Officer
	(Principal Executive Officer)
By	David P. Poroch
	Executive Vice President, Chief Financial Officer, and Treasurer
	(Principal Financial Officer)
By	/s/ Melissa K. Caen
	(Melissa K. Caen, Attorney-in-fact)

Date: April 27, 2022

137

EX-10.A1

Exhibit 10(a)1

SOUTHERN COMPANY

2021 EQUITY AND INCENTIVE COMPENSATION PLAN

FORM OF TERMS

PERFORMANCE SHARE AWARD

A Performance Share Award is subject to the following terms and conditions:

1.Award. A target number of performance share units (“Performance Shares” or “Performance Share Award”) is granted by the Compensation and Management Succession Committee (“Committee”) of The Southern Company (“Company”) Board of Directors to a Participant. The Performance Share Award provides the Participant an opportunity to earn shares of Southern Company Common Stock (“Common Stock”) based on Company performance over a three-year Performance Period (as defined below) against the performance goal measures set forth in Exhibit 1. Performance Share Awards are granted pursuant to and are governed by The Southern Company 2021 Equity and Incentive Compensation Plan, as amended from time to time (“Plan”).

2.Terms. Terms used in this Form of Terms that are not defined herein will have the meanings ascribed to them in the Plan or the Long-Term Incentive Program Document (“LTI Program Document”), an administrative document adopted by the Committee which is set forth at https:/mysource.southernco.com. The LTI Program Document also contains additional provisions that apply to Performance Share Awards. Performance Share Awards are subject to the terms and conditions set forth in the Plan, the LTI Program Document and any other administrative documents adopted by the Committee from time to time. If there is any inconsistency between the terms herein and the terms of the Plan, the LTI Program Document or any administrative document adopted by the Committee, the terms of the Plan, the LTI Program Document and the administrative document’s terms will supersede and replace the conflicting terms of this Form of Terms.

3.Performance Period. The period during which the performance goal measures apply (“Performance Period”) will be a three-year period that begins on January 1 of the year the Performance Share Award is granted to a Participant and ends on December 31 of the three-year period.

4.Number of Target Performance Shares and Deemed Dividends. A target number of Performance Shares are awarded to a Participant and allocated among the goals established by the Committee as set forth in Exhibit 1. No actual shares of Common Stock are issued to, or otherwise set aside for, the Participant at the time of grant.

The deemed dividends associated with the Performance Shares during the Performance Period shall be credited and treated as reinvested in additional Performance Shares. Reinvested dividends will not be received unless and until the Performance Share Award is paid out and will depend on Company achievement of the performance goals. If no Performance Shares are earned and paid out, no dividends will be paid out.

5.Establishing Performance Goal Measures. The performance goal measures will be established by the Committee.

1

6.Determining Payment of Performance Share Award. After the end of the Performance Period, a Participant shall receive between 0% and 200% of the Performance Share Award, as adjusted to reflect deemed dividend reinvestment, depending on Company performance measured against the performance goals approved by the Committee set forth on Exhibit 1. Each goal result will be determined and a payment percentage determined relative to the target amount of Performance Shares granted to the Participant. Prior to payment, the Committee shall certify that the requirements necessary to receive a payment under each performance goal have been met. Payment for performance between points is interpolated on a straight-line basis.

7.Vesting and Payment of Award. The Performance Share Award does not vest until the last day of the Performance Period (“Vesting Date”). A Participant must be an employee of the Company or a Subsidiary on the Vesting Date to receive payment, except in the event of Retirement, Death or Disability as described in the LTI Program Document.

See the LTI Program Document for additional information on the impact of certain employment events on the vesting of Performance Share Awards.

Performance Share Awards will be paid in unrestricted shares of Common Stock as soon as practicalfollowing the end of the Performance Period, but in no event later than March 15 immediately following the end of the Performance Period.

The Performance Share Award payment is subject to applicable withholding taxes. For purposes of tax calculations, the value of the Common Stock earned by a Participant will be determined based on the Fair Market Value on the payment date. The actual number of shares that a Participant may receive will be reduced by the number of shares reflecting the amount of withholding taxes.

8.Deferral of Payment. Participants in the Southern Company Deferred Compensation Plan may not defer receipt of Performance Share Award payments.

9.Transferability and Share Ownership. Performance Shares are not transferable or assignable in any manner except by will or the laws of descent and distribution. A Participant is not considered to own any shares of Common Stock based on the Performance Share Award until the Common Stock is issued to a Participant.

10.No Right to Employment. Neither a Performance Share Award nor this Form of Terms creates any right to employment or continuation of current employment or the right to any future Awards under the Plan. No provision of this Form of Terms shall be construed to affect in any manner the existing rights of the Company or its affiliates to suspend, terminate, alter or modify, whether or not for cause, the Participant’s employment relationship with the Company or its affiliates.

11.Impact on Other Plans. Neither the Performance Share Award nor the final payment of the Performance Share Award in Common Stock is considered “Compensation” for purposes of The Southern Company Employee Savings Plan or “Earnings” or “Pay” as defined in The Southern Company Pension Plan. Payments to Participants shall not be considered wages, salary, or compensation under any other employee benefit or

2

compensation plan or program sponsored by the Company or a Subsidiary, unless the explicit terms of such plan or program provide otherwise.

3

Exhibit 1 – Performance Goals1

Performance Measures. The number of shares of Common Stock that can be earned by a Participant under this Performance Share Award is based on the achievement of [_____] separate performance goals established by the Committee, as well as achievement of the credit quality threshold described below.

a.Company Relative Total Shareholder Return (TSR) measures Company stock price performance plus dividends relative to a peer group approved by the Committee. Relative TSR performance accounts for [__]% of a Participant’s long-term incentive grant value.

b.Return on Equity (ROE) measures the Southern Company ROE during the Performance Period. ROE performance accounts for [__]% of a Participant’s long-term incentive grant value.[

c.Carbon Reduction Goal measures Southern Company’s progress towards its 2030 greenhouse gas reduction goal during the Performance Period and accounts for 10% of the Participant’s long-term incentive grant value. The Participant’s Carbon Reduction Goal is measured in terms of megawatt changes over the Performance Period with a payout modifier for the Committee’s assessment of progress towards advancing the energy portfolio of the future (- 25% to 50%).]2

Credit Quality Threshold. The ROE goal described above is subject to a credit quality threshold as described in the LTI Program Document. If, at the end of the performance period, the credit ratings for the Company, Alabama Power Company and Georgia Power Company are below specified levels, there will be no payment associated with the ROE goal.

1 To be updated to reflect the appropriate weightings and metrics for each group of participants.

2 For use with Executive Officers who have a GHG-related goal metric.

4

SOUTHERN COMPANY

2021 EQUITY AND INCENTIVE COMPENSATION PLAN

FORM OF TERMS

RESTRICTED STOCK UNIT WITH PERFORMANCE MEASURE AWARD

A Restricted Stock Unit with performance measure (“RSU”) Award is subject to the following terms and conditions:

1.Award. A specific number of RSUs is granted by the Compensation and Management Succession Committee (“Committee”) of The Southern Company (“Company”) Board of Directors to a Participant. The RSU Award provides the Participant an opportunity to earn shares of Common Stock based on Company performance over a one-year Performance Period (as defined below) subject to the attainment of a performance measure set by the Committee. RSU Awards are granted pursuant to and are governed by The Southern Company 2021 Equity and Incentive Compensation Plan, as amended from time to time (“Plan”).

2.Terms. Terms used in this Form of Terms that are defined herein will have the meanings ascribed to them in the Plan or the Long-Term Incentive Program Document (“LTI Program Document”), an administrative document adopted by the Committee which is set forth at https:/mysource.southernco.com. The LTI Program Document also contains additional provisions that apply to RSU Awards. RSU Awards are subject to the terms and conditions set forth in the Plan, the LTI Program Document and any other administrative documents adopted by the Committee from time to time. If there is any inconsistency between the terms herein and the terms of the Plan, the LTI Program Document or any administrative document adopted by the Committee, the terms of the Plan, the LTI Program Document and the administrative document’s terms will supersede and replace the conflicting terms of this Form of Terms.

3.Number of RSUs and Deemed Dividends. A specific number of RSUs are determined and awarded to a Participant. The deemed dividends associated with the RSUs shall be credited and treated as reinvested in additional RSUs until each amount vests and is paid to the Participant.

4.Performance Period. The Performance Period is the period during which the performance measure set forth in Exhibit 1 will apply is the calendar year of the Date of Grant of the RSU Award.

5.Performance Measure. The performance measure will be established by the Committee and set forth in Exhibit 1 hereto. The Committee shall determine whether the performance measure was attained and, if so, shall certify such attainment (the “Certification Date”). If the performance measure is not attained, the RSUs shall be forfeited as of the Certification Date.

6.Vesting and Payment of Award. If the performance measure is attained, as certified by the Committee, the RSU Award vests one-third each year on the anniversary of the Date of Grant (“Vesting Date”) as follows:

Amount                    Vesting Date            

1/3 of RSU Award            Certification Date

1/3 of RSU Award            2-Year Anniversary of Date of Grant

1/3 of RSU Award            3-Year Anniversary of Date of Grant

Participant must be an employee of the Company or a Subsidiary on the applicable Vesting Date to receive payment, except as in the event of Retirement, Death or Disability as described in the LTI

1

Program Document. For the avoidance of doubt, no RSU Award will be payable to Participant in the event of Retirement unless the performance measure is attained.

See the LTI Program Document for additional information on the impact of certain employment events on the vesting and payment of RSU Awards.

RSU Awards will be paid in unrestricted shares of Common Stock as soon as practicalfollowing the Vesting Date but in no event later than 30 days following the Vesting Date.

Vested RSU Awards are subject to applicable withholding taxes. For purposes of tax calculations, the value of the vested Common Stock earned by a Participant will be determined based on the Fair Market Value on the Vesting Date. The actual number of shares that a Participant may receive will be reduced by the number of shares reflecting the amount of withholding taxes.

7.Deferral of Payout. Participants in the Southern Company Deferred Compensation Plan may not defer receipt of RSU Award payments.

8.Transferability and Share Ownership. RSUs are not transferable or assignable in any manner except by will or the laws of descent and distribution. A Participant is not considered to own any shares of Common Stock based on the RSU Award until after the Vesting Date and Common Stock is issued to a Participant.

9.No Right to Employment. Neither an RSU Award nor this Form of Terms creates any right to employment or continuation of current employment or the right to any future Awards under the Plan. No provision of this Form of Terms shall be construed to affect in any manner the existing rights of the Company or its affiliates to suspend, terminate, alter or modify, whether or not for cause, the Participant’s employment relationship with the Company or its affiliates.

10.Impact on Other Plans. Neither the RSU Award nor the payment of the RSU Award in Common Stock is considered “Compensation” for purposes of The Southern Company Employee Savings Plan or “Earnings” or “Pay” as defined in The Southern Company Pension Plan. Payments to Participants shall not be considered wages, salary, or compensation under any other employee benefit or compensation plan or program sponsored by the Company or a Subsidiary, unless the explicit terms of such plan or program provide otherwise.

2

Exhibit 1 – Performance Goal

Performance Measure. The Participant has the opportunity to earn shares of Common Stock based on the attainment of the following Company performance measure that has been established by the Committee:

[Year] Cash from Operations is greater than $[Amount] ([Prior Year] Dividends Paid)

3

EX-10.A2

Exhibit 10(a)2

FIFTH AMENDMENT
TO THE

SOUTHERN COMPANY
EMPLOYEE SAVINGS PLAN

WHEREAS, Southern Company Services, Inc. adopted the latest amendment and restatement of The Southern Company Employee Savings Plan (“Plan”), effective as of January 1, 2018;

WHEREAS, pursuant to Section 15.1 of the Plan, the Southern Company Employee Savings Plan Committee (“Administrative Committee”) may amend the Plan, provided the amendment either (a) does not involve a substantial increase in cost to any Employing Company, or (b) is necessary, proper, or desirable in order to comply with applicable laws or regulations enacted or promulgated by any federal or state governmental authority and to maintain the qualified status of the Plan; and

WHEREAS, the Administrative Committee, in its settlor capacity, desires to amend the Plan to provide that temporary employees and cooperative education employees who complete at least 1,000 hours of service in an eligibility computation period will be eligible to participate, but will not be automatically enrolled, in the Plan.

NOW, THEREFORE, pursuant to resolutions adopted on May 10, 2021, the Administrative Committee hereby amends the Plan as follows, effective as specified below:

1.

Effective as of July 1, 2021, Section 2.30 of the Plan is hereby amended by adding the following at the end thereof:

Notwithstanding the foregoing, any cooperative education employee or temporary employee who completes at least 1,000 Hours of Service in an eligibility computation period shall be an Eligible Employee who is eligible to participate in the Plan.

2.

Effective as of July 1, 2021, Section 3.1(b) of the Plan is hereby amended by deleting the first sentence and replacing it with the following:

Notwithstanding (a) above, each Eligible Employee (other than a cooperative education employee or a temporary employee) who is hired on or after December 1, 2017 (or on or after October 30, 2017 for an Eligible Employee having an AGL RSP account, or on or after July 1, 2017 for an Eligible Employee having a Nicor Thrift Plan account, as applicable) shall immediately participate in the Plan after 30 days of employment or such Enrollment Date that occurs as soon as administratively practicable thereafter.

NAI-1516935464v1

3.

Except as amended by this Fifth Amendment, the Plan shall remain in full force and effect.

IN WITNESS WHEREOF, the Administrative Committee, through its authorized representative, has adopted this Fifth Amendment to The Southern Company Employee Savings Plan, as amended and restated as of January 1, 2018, this 13th day of May, 2021.

EMPLOYEE SAVINGS PLAN COMMITTEE
By:	/s/James M. Garvie
Name:	James M. Garvie
Its:	Chairperson

2

NAI-1516935464v1

EX-10.A3

Exhibit 10(a)3

SIXTH AMENDMENT TO THE

SOUTHERN COMPANY EMPLOYEE SAVINGS PLAN

WHEREAS, Southern Company Services, Inc. adopted the latest amendment and restatement of The Southern Company Employee Savings Plan (“Plan”), effective as of January 1, 2018;

WHEREAS, pursuant to Section 15.1 of the Plan, the Southern Company Employee Savings Plan Committee (“Administrative Committee”) may amend the Plan, provided the amendment either (a) does not involve a substantial increase in cost to any Employing Company, or (b) is necessary, proper, or desirable in order to comply with applicable laws or regulations enacted or promulgated by any federal or state governmental authority and to maintain the qualified status of the Plan; and

WHEREAS, the Administrative Committee, in its settlor capacity, desires to amend the Plan to provide for cessation of participation for employees of Sequent Energy Management, LP and Sequent Energy Canada Corp. who are no longer Employees due to the divestiture that occurred on July 1, 2021, and to provide for full vesting for the Accounts of such employees.

NOW, THEREFORE, pursuant to resolutions adopted on November 8, 2021, the Administrative Committee hereby amends the Plan as follows, effective as specified below:

1.

The Plan is hereby amended by adding a new paragraph (g) to Section 3.7 to read as follows:

(g)    Sequent.

(1)    Cessation of Participation. Effective as of July 1, 2021, (i) Sequent Energy Management, LP and Sequent Energy Canada Corp. and their direct and indirect subsidiaries will cease to be affiliated companies of Southern Company Gas for purposes of determining Employing Company status under the Plan; and (ii) Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp. will cease to be eligible to actively participate in the Plan.

(2)    Vesting Acceleration. Effective as of July 1, 2021, Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp. will be deemed to be fully vested in their Accounts for all purposes hereunder.

2.

Except as amended by this Sixth Amendment, the Plan shall remain in full force and effect.

SGR/26149302.1

IN WITNESS WHEREOF, the Administrative Committee, through its authorized representative, has adopted this Sixth Amendment to The Southern Company Employee Savings Plan, as amended and restated as of January 1, 2018, this 1st day of December, 2021.

EMPLOYEE SAVINGS PLAN COMMITTEE
By:	/s/James M. Garvie
Name:	James M. Garvie
Its:	Chairperson

SGR/26149302.1

EX-10.A4

Exhibit 10(a)4

FOURTH AMENDMENT TO THE SOUTHERN COMPANY

DEFERRED COMPENSATION PLAN

WHEREAS, the Board of Directors of Southern Company Services, Inc. heretofore established and adopted the Southern Company Deferred Compensation Plan, as amended and restated effective January 1, 2018 (the “Plan”);

WHEREAS, under Section 8.3 of the Plan, the Benefits Administration Committee (the “Committee”) may amend the Plan, provided the amendment either (a) does not involve a substantial increase in cost to any Employing Company, or (b) is necessary, proper, or desirable in order to comply with applicable laws or regulations enacted or promulgated by any federal or state governmental authority; and

WHEREAS, the Committee, in its settlor capacity, desires to amend the Plan to provide for cessation of active participation for employees of Sequent Energy Management, LP and Sequent Energy Canada Corp. who are no longer Employees due to the divestiture that occurred on July 1, 2021, and to provide for full vesting for the benefits of such employees.

NOW, THEREFORE, pursuant to resolutions adopted on November 8, 2021, the Committee hereby amends the Plan as follows, effective as specified herein:

1.

The Plan is hereby amended by adding a new paragraph (g) to Section 4.4, as follows:

(g)    Sequent.

(1)    Cessation of Participation. Effective as of July 1, 2021, (i) Sequent Energy Management, LP and Sequent Energy Canada Corp. and their direct and indirect subsidiaries will cease to be affiliated companies of Southern Company Gas for purposes of determining Employing Company status under the Plan; and (ii) Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp., will cease to be eligible to actively participate in the Plan.

(2)    Vesting Acceleration. Effective as of July 1, 2021, Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp.will be deemed to be fully vested for all purposes hereunder.

2.

Except as amended herein by this Fourth Amendment, the Plan shall remain in full force and effect.

SGR/26157302.1

IN WITNESS WHEREOF, the Committee, through its authorized representative, hasadopted this Fourth Amendment to the Southern Company Deferred Compensation Plan, as amended and restated as of January 1, 2018, this 1st day of December, 2021.

BENEFITS ADMINISTRATION COMMITTEE
By:	/s/James M. Garvie
Name:	James M. Garvie
Its:	Chairperson

2

SGR/26157302.1

EX-10.A5

Exhibit 10(a)5

EIGHTH AMENDMENT TO THE SOUTHERN COMPANY

SUPPLEMENTAL BENEFIT PLAN

WHEREAS, Southern Company Services, Inc. heretofore established and adopted the Southern Company Supplemental Benefit Plan, as amended and restated effective June 30, 2016 (the “Plan”);

WHEREAS, under Section 6.2 of the Plan, the Benefits Administration Committee (“Administrative Committee”) may amend the Plan, provided the amendment either (a) does not involve a substantial increase in cost to any Employing Company (as defined in the Plan), or (b) is necessary, proper, or desirable in order to comply with applicable laws or regulations enacted or promulgated by any federal or state governmental authority; and

WHEREAS, the Administrative Committee, by Resolution on November 8, 2021, has determined it is appropriate to amend the Plan to provide for cessation of active participation for employees of Sequent Energy Management, LP and Sequent Energy Canada Corp. who are no longer Employees due to the divestiture that occurred on July 1, 2021, and to provide for full vesting for the benefits of such employees.

NOW, THEREFORE,effective as specified herein, the Plan is hereby amended as follows:

1.

The Plan is hereby amended by adding a new paragraph (g) to Section 4.3, as follows:

(g)    Sequent.

(1)    Cessation of Participation. Effective as of July 1, 2021, (i) Sequent Energy Management, LP and Sequent Energy Canada Corp. and their direct and indirect subsidiaries will cease to be affiliated companies of Southern Company Gas for purposes of determining Employing Company status under the Plan; and (ii) Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp., will cease to be eligible to actively participate in the Plan.

(2)    Vesting Acceleration. Effective as of July 1, 2021, Participants who cease to be Employees due to the sale of Sequent Energy Management, LP and Sequent Energy Canada Corp. will be deemed to be fully vested in their benefits and Accounts for all purposes hereunder.

2.

Except as amended herein by this Eighth Amendment, the Plan shall remain in full force and effect.

SGR/26151365.1

IN WITNESS WHEREOF, the Administrative Committee, through its authorized representative, has adopted this Eighth Amendment to the Southern Company Supplemental Benefit Plan, as amended and restated as of June 30, 2016, this 1st day of December, 2021.

BENEFITS ADMINISTRATION COMMITTEE
By:	/s/James M. Garvie
Name:	James M. Garvie
Its:	Chairperson

2

SGR/26151365.1

EX-31.A1

Exhibit 31(a)1

THE SOUTHERN COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Thomas A. Fanning, certify that:

1.I have reviewed this quarterly report on Form 10-Q of The Southern Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and
Chief Executive Officer

EX-31.A2

Exhibit 31(a)2

THE SOUTHERN COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Daniel S. Tucker, certify that:

1.I have reviewed this quarterly report on Form 10-Q of The Southern Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date: April 27, 2022

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President and Chief Financial Officer

EX-31.B1

Exhibit 31(b)1

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Mark A. Crosswhite, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Alabama Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

EX-31.B2

Exhibit 31(b)2

ALABAMA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Philip C. Raymond, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Alabama Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President, Chief Financial Officer
and Treasurer

EX-31.C1

Exhibit 31(c)1

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Christopher C. Womack, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Georgia Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Christopher C. Womack

Christopher C. Womack

Chairman, President and Chief Executive Officer

EX-31.C2

Exhibit 31(c)2

GEORGIA POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Aaron P. Abramovitz, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Georgia Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Aaron P. Abramovitz

Aaron P. Abramovitz

Executive Vice President, Chief Financial Officer and Treasurer

EX-31.D1

Exhibit 31(d)1

MISSISSIPPI POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Anthony L. Wilson, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Mississippi Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and
 Chief Executive Officer

EX-31.D2

Exhibit 31(d)2

MISSISSIPPI POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Moses H. Feagin, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Mississippi Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Moses H. Feagin

Moses H. Feagin

Senior Vice President, Treasurer and
Chief Financial Officer

EX-31.E1

Exhibit 31(e)1

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Christopher Cummiskey, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:   April 27, 2022

/s/Christopher Cummiskey

Christopher Cummiskey

Chairman and Chief Executive Officer

EX-31.E2

Exhibit 31(e)2

SOUTHERN POWER COMPANY

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, Elliott L. Spencer, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Power Company;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Elliott L. Spencer

Elliott L. Spencer

Senior Vice President, Chief
Financial Officer and Treasurer

EX-31.F1

Exhibit 31(f)1

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF EXECUTIVE OFFICER

I, Kimberly S. Greene, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Company Gas;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President and Chief Executive Officer

EX-31.F2

Exhibit 31(f)2

SOUTHERN COMPANY GAS

CERTIFICATION OF CHIEF FINANCIAL OFFICER

I, David P. Poroch, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Southern Company Gas;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

Date:  April 27, 2022

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial
Officer and Treasurer

EX-32.A

Exhibit 32(a)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of The Southern Company for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of The Southern Company for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of The Southern Company for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of The Southern Company.

/s/Thomas A. Fanning

Thomas A. Fanning

Chairman, President and
Chief Executive Officer

/s/Daniel S. Tucker

Daniel S. Tucker

Executive Vice President and
Chief Financial Officer

April 27, 2022

EX-32.B

Exhibit 32(b)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Alabama Power Company for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of Alabama Power Company.

/s/Mark A. Crosswhite

Mark A. Crosswhite

Chairman, President and Chief Executive Officer

/s/Philip C. Raymond

Philip C. Raymond

Executive Vice President,
Chief Financial Officer and Treasurer

April 27, 2022

EX-32.C

Exhibit 32(c)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Georgia Power Company for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of Georgia Power Company.

/s/Christopher C. Womack

Christopher C. Womack

Chairman, President and Chief Executive Officer

/s/Aaron P. Abramovitz

Aaron P. Abramovitz

Executive Vice President, Chief Financial Officer and Treasurer

April 27, 2022

EX-32.D

Exhibit 32(d)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Mississippi Power Company for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of Mississippi Power Company.

/s/Anthony L. Wilson

Anthony L. Wilson

Chairman, President and Chief Executive Officer

/s/Moses H. Feagin

Moses H. Feagin

Senior Vice President, Treasurer and
Chief Financial Officer

April 27, 2022

EX-32.E

Exhibit 32(e)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Southern Power Company for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of Southern Power Company.

/s/Christopher Cummiskey

Christopher Cummiskey

Chairman and Chief Executive Officer

/s/Elliott L. Spencer

Elliott L. Spencer

Senior Vice President, Chief Financial Officer and Treasurer

April 27, 2022

EX-32.F

Exhibit 32(f)

CERTIFICATION

18 U.S.C. SECTION 1350

AS ADOPTED PURSUANT TO SECTION 906 OF THE

SARBANES-OXLEY ACT OF 2002

In connection with the accompanying Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended March 31, 2022, we, the undersigned, hereby certify pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, to the best of our individual knowledge and belief, that:

(1)such Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended March 31, 2022, which this statement accompanies, fully complies with the requirements of Section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)the information contained in such Quarterly Report on Form 10-Q of Southern Company Gas for the quarter ended March 31, 2022, fairly presents, in all material respects, the financial condition and results of operations of Southern Company Gas.

/s/Kimberly S. Greene

Kimberly S. Greene

Chairman, President and Chief Executive Officer

/s/David P. Poroch

David P. Poroch

Executive Vice President, Chief Financial

Officer and Treasurer

April 27, 2022

XML

Cover Page	3 Months Ended
	Mar. 31, 2022 shares
Document Information [Line Items]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Mar. 31, 2022
Document Transition Report	false
Entity File Number	1-3526
Entity Registrant Name	The Southern Company
Entity Tax Identification Number	58-0690070
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	30 Ivan Allen Jr. Boulevard, N.W.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-5000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,062,524,675
Entity Central Index Key	0000092122
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q1
Current Fiscal Year End Date	--12-31
Common Stock, par value $5 per share
Document Information [Line Items]
Title of 12(b) Security	Common Stock, par value $5 per share
Trading Symbol	SO
Security Exchange Name	NYSE
Series 2017B 5.25% Junior Subordinated Notes due 2077
Document Information [Line Items]
Title of 12(b) Security	Series 2017B 5.25% Junior Subordinated Notes due 2077
Trading Symbol	SOJC
Security Exchange Name	NYSE
2019 Series A Corporate Units
Document Information [Line Items]
Title of 12(b) Security	2019 Series A Corporate Units
Trading Symbol	SOLN
Security Exchange Name	NYSE
Series 2020A 4.95% Junior Subordinated Notes due 2080
Document Information [Line Items]
Title of 12(b) Security	Series 2020A 4.95% Junior Subordinated Notes due 2080
Trading Symbol	SOJD
Security Exchange Name	NYSE
Series 2020C 4.20% Junior Subordinated Notes due 2060
Document Information [Line Items]
Title of 12(b) Security	Series 2020C 4.20% Junior Subordinated Notes due 2060
Trading Symbol	SOJE
Security Exchange Name	NYSE
Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081
Document Information [Line Items]
Title of 12(b) Security	Series 2021B 1.875% Fixed-to-Fixed Reset Rate Junior Subordinated Notes due 2081
Trading Symbol	SO 81
Security Exchange Name	NYSE
ALABAMA POWER CO
Document Information [Line Items]
Entity File Number	1-3164
Entity Registrant Name	Alabama Power Company
Entity Tax Identification Number	63-0004250
Entity Incorporation, State or Country Code	AL
Entity Address, Address Line One	600 North 18th Street
Entity Address, City or Town	Birmingham
Entity Address, State or Province	AL
Entity Address, Postal Zip Code	35203
City Area Code	205
Local Phone Number	257-1000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	30,537,500
Entity Central Index Key	0000003153
ALABAMA POWER CO | 5.00% Series Class A Preferred Stock
Document Information [Line Items]
Title of 12(b) Security	5.00% Series Class A Preferred Stock
Trading Symbol	ALP PR Q
Security Exchange Name	NYSE
GEORGIA POWER CO
Document Information [Line Items]
Entity File Number	1-6468
Entity Registrant Name	Georgia Power Company
Entity Tax Identification Number	58-0257110
Entity Incorporation, State or Country Code	GA
Entity Address, Address Line One	241 Ralph McGill Boulevard, N.E.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-6526
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	9,261,500
Entity Central Index Key	0000041091
GEORGIA POWER CO | Series 2017A 5.00% Junior Subordinated Notes due 2077
Document Information [Line Items]
Title of 12(b) Security	Series 2017A 5.00% Junior Subordinated Notes due 2077
Trading Symbol	GPJA
Security Exchange Name	NYSE
MISSISSIPPI POWER CO
Document Information [Line Items]
Entity File Number	001-11229
Entity Registrant Name	Mississippi Power Company
Entity Tax Identification Number	64-0205820
Entity Incorporation, State or Country Code	MS
Entity Address, Address Line One	2992 West Beach Boulevard
Entity Address, City or Town	Gulfport
Entity Address, State or Province	MS
Entity Address, Postal Zip Code	39501
City Area Code	228
Local Phone Number	864-1211
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,121,000
Entity Central Index Key	0000066904
SOUTHERN POWER CO
Document Information [Line Items]
Entity File Number	001-37803
Entity Registrant Name	Southern Power Company
Entity Tax Identification Number	58-2598670
Entity Incorporation, State or Country Code	DE
Entity Address, Address Line One	30 Ivan Allen Jr. Boulevard, N.W.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30308
City Area Code	404
Local Phone Number	506-5000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	1,000
Entity Central Index Key	0001160661
SOUTHERN POWER CO | Series 2016A 1.000% Senior Notes due 2022
Document Information [Line Items]
Title of 12(b) Security	Series 2016A 1.000% Senior Notes due 2022
Trading Symbol	SO/22B
Security Exchange Name	NYSE
SOUTHERN POWER CO | Series 2016B 1.850% Senior Notes due 2026
Document Information [Line Items]
Title of 12(b) Security	Series 2016B 1.850% Senior Notes due 2026
Trading Symbol	SO/26A
Security Exchange Name	NYSE
SOUTHERN Co GAS
Document Information [Line Items]
Entity File Number	1-14174
Entity Registrant Name	Southern Company Gas
Entity Tax Identification Number	58-2210952
Entity Incorporation, State or Country Code	GA
Entity Address, Address Line One	Ten Peachtree Place, N.E.
Entity Address, City or Town	Atlanta
Entity Address, State or Province	GA
Entity Address, Postal Zip Code	30309
City Area Code	404
Local Phone Number	584-4000
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Non-accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding (in shares)	100
Entity Central Index Key	0001004155

XML

Condensed Consolidated Statements of Income (Unaudited) - Southern - USD ($) shares in Millions, $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Gain on dispositions, net	(23)	(44)
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Allowance for equity funds used during construction	51	46
Earnings from equity method investments	46	45
Interest expense, net of amounts capitalized	(462)	(450)
Other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Consolidated Net Income	991	1,107
Dividends on preferred stock of subsidiaries	4	4
Net loss attributable to noncontrolling interests	(45)	(32)
Net Income	$ 1,032	$ 1,135
Earnings per share -
Basic (in dollars per share)	$ 0.97	$ 1.07
Diluted (in dollars per share)	$ 0.97	$ 1.06
Average number of shares of common stock outstanding — (in millions)
Basic (in shares)	1,063	1,060
Diluted (in shares)	1,069	1,066
Retail electric revenues
Operating Revenues:
Total operating revenues	$ 3,613	$ 3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Natural gas
Operating Expenses:
Less Gross Gas Costs	1,095	583
Alternative revenue programs
Operating Revenues:
Total operating revenues	0	2
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
Fuel
Operating Expenses:
Less Gross Gas Costs	1,111	848
Purchased power
Operating Expenses:
Less Gross Gas Costs	$ 232	$ 207

XML

Condensed Consolidated Statements of Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Total operating revenues	$ 6,648	$ 5,910
Natural Gas
Total operating revenues	2,058	1,694
Alternative revenue programs
Total operating revenues	$ 0	$ 2

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Net income	$ 991	$ 1,107
Qualifying hedges:
Changes in fair value, net of tax	19	(30)
Reclassification adjustment for amounts included in net income, net of tax	20	55
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	3	3
Total other comprehensive income	42	28
Comprehensive Income	1,033	1,135
Dividends on preferred stock of subsidiaries	4	4
Comprehensive loss attributable to noncontrolling interests	(45)	(32)
Comprehensive Income	$ 1,074	$ 1,163

XML

Condensed Consolidated Statements of Comprehensive Income (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Comprehensive Income [Abstract]
Changes in fair value, tax	$ 8	$ (10)
Qualifying hedges, reclassification adjustment, tax	6	18
Reclassification adjustment for amounts included in net income, tax	$ 1	$ 1

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Allowance for equity funds used during construction	(51)	(46)
Pension, postretirement, and other employee benefits	(123)	(78)
Settlement of asset retirement obligations	(87)	(109)
Stock based compensation expense	85	83
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Storm damage accruals	52	54
Gain on dispositions, net	(20)	(41)
Natural gas cost under recovery – long-term	162	(185)
Retail fuel cost under recovery – long-term	(130)	0
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Prepayments	(86)	(98)
-Materials and supplies	(28)	(27)
-Natural gas for sale, net of temporary LIFO liquidation	450	456
-Natural gas cost under recovery	(40)	(487)
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Accrued compensation	(470)	(417)
-Accrued interest	(128)	(90)
-Retail fuel cost over recovery	0	(53)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(1,419)	(1,678)
Nuclear decommissioning trust fund purchases	(294)	(550)
Nuclear decommissioning trust fund sales	289	546
Cost of removal, net of salvage	(227)	(85)
Change in construction payables, net	23	(116)
Payments pursuant to LTSAs	(37)	(60)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Financing Activities:
Increase in notes payable	137	182
Proceeds —
Long-term debt	700	2,150
Short-term borrowings	850	325
Common stock	38	14
Redemptions and repurchases —
Long-term debt	(977)	(384)
Short-term borrowings	(100)	(25)
Capital contributions from noncontrolling interests	73	313
Distributions to noncontrolling interests	(97)	(46)
Payment of common stock dividends	(702)	(678)
Other financing activities	(115)	(117)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Income taxes, net	(8)	(51)
Noncash transactions —
Accrued property additions at year-end	863	872
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Right-of-use assets obtained under leases	3	76
Reassessment of right-of-use assets under operating leases	$ 40	$ 0

XML

Condensed Consolidated Statements of Cash Flows (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Cash Flows [Abstract]
Net cash paid for capitalized interest	$ 23	$ 21

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Condensed Consolidated Balance Sheets (Unaudited) - Southern - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Unbilled revenues	638	711
Other accounts and notes	509	523
Accumulated provision for uncollectible accounts	(89)	(78)
Materials and supplies	1,571	1,543
Fossil fuel for generation	411	450
Natural gas for sale	121	362
Prepaid expenses	739	330
Assets from risk management activities, net of collateral	405	151
Regulatory assets – asset retirement obligations	241	219
Natural gas cost under recovery	306	266
Other regulatory assets	576	653
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Nuclear fuel, at amortized cost	839	824
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Goodwill	5,280	5,280
Nuclear decommissioning trusts, at fair value	2,403	2,542
Equity investments in unconsolidated subsidiaries	1,293	1,282
Other intangible assets, net of amortization	435	445
Miscellaneous property and investments	633	653
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693	1,701
Deferred charges related to income taxes	833	824
Prepaid pension costs	1,772	1,657
Unamortized loss on reacquired debt	257	258
Regulatory assets – asset retirement obligations, deferred	5,683	5,466
Other regulatory assets, deferred	5,372	5,577
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Notes payable	2,330	1,440
Accounts payable	2,251	2,169
Customer deposits	454	479
Accrued taxes —
Accrued income taxes	57	50
Other accrued taxes	415	641
Accrued interest	404	533
Accrued compensation	574	1,070
Asset retirement obligations	695	697
Operating lease obligations	245	250
Other regulatory liabilities	711	563
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Deferred credits related to income taxes	5,365	5,401
Accumulated deferred ITCs	2,196	2,216
Employee benefit obligations	1,526	1,550
Operating lease obligations, deferred	1,521	1,503
Asset retirement obligations, deferred	11,016	10,990
Other cost of removal obligations	2,030	2,103
Other regulatory liabilities, deferred	526	485
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Redeemable preferred stock	291	291
Common Stockholder's Equity (See accompanying statements)	32,629	32,276
Total Liabilities and Stockholders' Equity	$ 128,639	$ 127,534

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Condensed Consolidated Balance Sheets (Unaudited) - Southern (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Other intangible assets, amortization	$ 317	$ 307

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - Southern - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Treasury	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests
Beginning balance (in shares) at Dec. 31, 2020		1,058	1
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ (46)	$ 11,834	$ 11,311	$ (395)	$ 4,262
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	1,103				1,135		(32)
Other comprehensive income (loss)	28					28
Stock issued (in shares)		2
Stock issued	14	$ 5		9
Stock-based compensation	9			9
Cash dividends on common stock	(678)				(678)
Capital contributions from noncontrolling interests	403						403
Distributions to noncontrolling interests	(46)						(46)
Other	1			2			(1)
Ending balance (in shares) at Mar. 31, 2021		1,060	1
Ending balance at Mar. 31, 2021	33,068	$ 5,273	$ (46)	11,854	11,768	(367)	4,586
Beginning balance (in shares) at Dec. 31, 2021		1,061	1
Beginning balance at Dec. 31, 2021	32,276	$ 5,279	$ (47)	11,950	10,929	(237)	4,402
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Consolidated net income (loss)	987				1,032		(45)
Other comprehensive income (loss)	42					42
Stock issued (in shares)		3
Stock issued	38	$ 7		31
Stock-based compensation	6			6
Cash dividends on common stock	(702)				(702)
Capital contributions from noncontrolling interests	73						73
Distributions to noncontrolling interests	(98)						(98)
Other	7		$ (2)	7	2
Ending balance (in shares) at Mar. 31, 2022		1,064	1
Ending balance at Mar. 31, 2022	$ 32,629	$ 5,286	$ (49)	$ 11,994	$ 11,261	$ (195)	$ 4,332

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - Southern (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.66	$ 0.64

XML

Condensed Statements of Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Allowance for equity funds used during construction	51	46
Interest expense, net of amounts capitalized	(462)	(450)
Total other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Net income	991	1,107
Dividends on preferred stock of subsidiaries	4	4
Net Income	1,032	1,135
Retail electric revenues
Operating Revenues:
Total operating revenues	3,613	3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
Fuel
Operating Expenses:
Less Gross Gas Costs	1,111	848
Purchased power
Operating Expenses:
Less Gross Gas Costs	232	207
Alabama Power
Operating Revenues:
Total operating revenues	1,649	1,559
Operating Expenses:
Other operations and maintenance	409	361
Depreciation and amortization	215	211
Taxes other than income taxes	104	103
Total operating expenses	1,154	1,046
Operating Income	495	513
Other Income and (Expense):
Allowance for equity funds used during construction	16	12
Interest expense, net of amounts capitalized	(89)	(84)
Total other income (expense), net	36	32
Total other income and (expense)	(37)	(40)
Earnings Before Income Taxes	458	473
Income taxes (benefit)	107	110
Net income	351	363
Dividends on preferred stock of subsidiaries	4	4
Net Income	347	359
Alabama Power | Retail electric revenues
Operating Revenues:
Total operating revenues	1,379	1,352
Alabama Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	114	92
Alabama Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	65	32
Alabama Power | Other revenues
Operating Revenues:
Total operating revenues	91	83
Alabama Power | Fuel
Operating Expenses:
Less Gross Gas Costs	333	291
Alabama Power | Purchased power
Operating Expenses:
Less Gross Gas Costs	67	50
Alabama Power | Purchased power, affiliates
Operating Expenses:
Less Gross Gas Costs	$ 26	$ 30

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Condensed Statements of Comprehensive Income (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net income	$ 991	$ 1,107
Qualifying hedges:
Changes in fair value, net of tax	19	(30)
Reclassification adjustment for amounts included in net income, net of tax	20	55
Total other comprehensive income	42	28
Comprehensive Income	1,033	1,135
Alabama Power
Net income	351	363
Qualifying hedges:
Changes in fair value, net of tax	(1)	0
Reclassification adjustment for amounts included in net income, net of tax	1	1
Total other comprehensive income	0	1
Comprehensive Income	$ 351	$ 364

XML

Condensed Statements of Comprehensive Income (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Changes in fair value, tax	$ 8	$ (10)
Qualifying hedges, reclassification adjustment, tax	6	18
Alabama Power
Changes in fair value, tax	(1)	0
Qualifying hedges, reclassification adjustment, tax	$ 0	$ 0

XML

Condensed Statements of Cash Flows (Unaudited) - APC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Pension, postretirement, and other employee benefits	(123)	(78)
Settlement of asset retirement obligations	(87)	(109)
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Prepayments	(86)	(98)
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Accrued compensation	(470)	(417)
-Retail fuel cost over recovery	0	(53)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Property additions	(1,419)	(1,678)
Nuclear decommissioning trust fund purchases	(294)	(550)
Nuclear decommissioning trust fund sales	289	546
Cost of removal, net of salvage	(227)	(85)
Change in construction payables, net	23	(116)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Redemptions and repurchases —
Payment of common stock dividends	(702)	(678)
Other financing activities	(115)	(117)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Noncash transactions —
Accrued property additions at year-end	863	872
Right-of-use assets obtained under leases	3	76
Alabama Power
Operating Activities:
Net income (loss)	351	363
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	250	248
Deferred income taxes	35	33
Pension, postretirement, and other employee benefits	(48)	(29)
Settlement of asset retirement obligations	(38)	(49)
Retail fuel cost under recovery – long-term	(46)	0
Other, net	(27)	(14)
Changes in certain current assets and liabilities —
-Receivables	(4)	40
-Fossil fuel stock	23	38
-Prepayments	(85)	(73)
-Other current assets	(10)	(16)
-Accounts payable	(237)	(299)
-Accrued taxes	102	104
-Accrued compensation	(99)	(105)
-Retail fuel cost over recovery	0	(18)
-Other current liabilities	(13)	(9)
Net cash provided from operating activities	154	214
Investing Activities:
Property additions	(343)	(466)
Nuclear decommissioning trust fund purchases	(72)	(310)
Nuclear decommissioning trust fund sales	72	310
Cost of removal, net of salvage	(60)	(23)
Change in construction payables, net	39	32
Other investing activities	(1)	(9)
Net cash used for investing activities	(365)	(466)
Proceeds —
Senior notes	700	0
Redemptions and repurchases —
Senior notes	(550)	0
Capital contributions from parent company	625	600
Payment of common stock dividends	(254)	(246)
Other financing activities	(17)	(13)
Net cash provided from (used for) financing activities	504	341
Net Change in Cash, Cash Equivalents, and Restricted Cash	293	89
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,060	530
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,353	619
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	110	93
Noncash transactions —
Accrued property additions at year-end	188	198
Right-of-use assets obtained under leases	$ 1	$ 1

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Condensed Statements of Cash Flows (Unaudited) - APC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net cash paid for capitalized interest	$ 23	$ 21
Alabama Power
Net cash paid for capitalized interest	$ 4	$ 3

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Condensed Balance Sheets (Unaudited) - APC - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Unbilled revenues	638	711
Other accounts and notes	509	523
Accumulated provision for uncollectible accounts	(89)	(78)
Fossil fuel for generation	411	450
Materials and supplies	1,571	1,543
Prepaid expenses	739	330
Other regulatory assets	576	653
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Nuclear fuel, at amortized cost	839	824
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,403	2,542
Equity investments in unconsolidated subsidiaries	1,293	1,282
Miscellaneous property and investments	633	653
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693	1,701
Deferred charges related to income taxes	833	824
Regulatory assets – asset retirement obligations, deferred	5,683	5,466
Other regulatory assets, deferred	5,372	5,577
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Accounts payable —
Customer deposits	454	479
Accrued interest	404	533
Accrued compensation	574	1,070
Asset retirement obligations	695	697
Other regulatory liabilities	711	563
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Deferred credits related to income taxes	5,365	5,401
Accumulated deferred ITCs	2,196	2,216
Employee benefit obligations	1,526	1,550
Operating lease obligations, deferred	1,521	1,503
Asset retirement obligations, deferred	11,016	10,990
Other cost of removal obligations	2,030	2,103
Other regulatory liabilities, deferred	526	485
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Redeemable preferred stock	291	291
Common Stockholder's Equity (See accompanying statements)	32,629	32,276
Total Liabilities and Stockholders' Equity	128,639	127,534
Alabama Power
Current Assets:
Cash and cash equivalents	1,353	1,060
Receivables —
Customer accounts	417	410
Unbilled revenues	127	138
Affiliated	36	37
Other accounts and notes	64	55
Accumulated provision for uncollectible accounts	(15)	(14)
Fossil fuel for generation	136	159
Materials and supplies	550	548
Prepaid expenses	126	41
Other regulatory assets	191	208
Other current assets	131	67
Total current assets	3,116	2,709
Property, Plant, and Equipment:
In service	33,333	33,135
Less: Accumulated depreciation	10,451	10,313
Plant in service, net of depreciation	22,882	22,822
Nuclear fuel, at amortized cost	246	247
Construction work in progress	1,249	1,147
Total property, plant, and equipment	24,377	24,216
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,257	1,325
Equity investments in unconsolidated subsidiaries	57	57
Miscellaneous property and investments	126	126
Total other property and investments	1,440	1,508
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	97	108
Deferred charges related to income taxes	243	240
Prepaid pension and other postretirement benefit costs	546	513
Regulatory assets – asset retirement obligations, deferred	1,663	1,547
Other regulatory assets, deferred	1,717	1,807
Other deferred charges and assets	371	334
Total deferred charges and other assets	4,637	4,549
Total Assets	33,570	32,982
Current Liabilities:
Securities due within one year	201	751
Accounts payable —
Affiliated	194	309
Other	372	459
Customer deposits	106	106
Accrued taxes	200	98
Accrued interest	77	100
Accrued compensation	124	219
Asset retirement obligations	322	320
Other regulatory liabilities	148	215
Other current liabilities	128	125
Total current liabilities	1,872	2,702
Long-term Debt	9,631	8,936
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,619	3,573
Deferred credits related to income taxes	1,959	1,968
Accumulated deferred ITCs	86	88
Employee benefit obligations	179	171
Operating lease obligations, deferred	64	66
Asset retirement obligations, deferred	4,013	4,014
Other cost of removal obligations	144	192
Other regulatory liabilities, deferred	224	210
Other deferred credits and liabilities	56	58
Total deferred credits and other liabilities	10,344	10,340
Total Liabilities	21,847	21,978
Redeemable preferred stock	291	291
Common Stockholder's Equity (See accompanying statements)	11,432	10,713
Total Liabilities and Stockholders' Equity	$ 33,570	$ 32,982

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Condensed Statements of Common Stockholders' Equity (Unaudited) - APC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Alabama Power	Alabama Power Common Stock	Alabama Power Paid-In Capital	Alabama Power Retained Earnings (Accumulated Deficit)	Alabama Power Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020		1,058					31
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 9,810	$ 1,222	$ 5,413	$ 3,194	$ (19)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	1,135					359			359
Capital contributions from parent company						602		602
Other comprehensive income (loss)	28				28	1				1
Cash dividends on common stock	(678)			(678)		(246)			(246)
Ending balance (in shares) at Mar. 31, 2021		1,060					31
Ending balance at Mar. 31, 2021	33,068	$ 5,273	11,854	11,768	(367)	10,526	$ 1,222	6,015	3,307	(18)
Beginning balance (in shares) at Dec. 31, 2021		1,061					31
Beginning balance at Dec. 31, 2021	32,276	$ 5,279	11,950	10,929	(237)	10,713	$ 1,222	6,056	3,448	(13)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income after dividends on preferred stock	1,032					347			347
Capital contributions from parent company						626		626
Other comprehensive income (loss)	42				42
Cash dividends on common stock	(702)			(702)		(254)			(254)
Ending balance (in shares) at Mar. 31, 2022		1,064					31
Ending balance at Mar. 31, 2022	$ 32,629	$ 5,286	$ 11,994	$ 11,261	$ (195)	$ 11,432	$ 1,222	$ 6,682	$ 3,541	$ (13)

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Condensed Statements of Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Allowance for equity funds used during construction	51	46
Interest expense, net of amounts capitalized	(462)	(450)
Other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Consolidated Net Income	991	1,107
Retail electric revenues
Operating Revenues:
Total operating revenues	3,613	3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
Fuel
Operating Expenses:
Less Gross Gas Costs	1,111	848
Purchased power
Operating Expenses:
Less Gross Gas Costs	232	207
Georgia Power
Operating Revenues:
Total operating revenues	2,208	1,970
Operating Expenses:
Other operations and maintenance	517	474
Depreciation and amortization	351	338
Taxes other than income taxes	125	116
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Total operating expenses	1,768	1,569
Operating Income	440	401
Other Income and (Expense):
Allowance for equity funds used during construction	32	31
Interest expense, net of amounts capitalized	(107)	(104)
Other income (expense), net	50	41
Total other income and (expense)	(25)	(32)
Earnings Before Income Taxes	415	369
Income taxes (benefit)	30	18
Consolidated Net Income	385	351
Georgia Power | Retail electric revenues
Operating Revenues:
Total operating revenues	2,017	1,787
Georgia Power | Wholesale Electric
Operating Revenues:
Total operating revenues	66	43
Georgia Power | Other revenues
Operating Revenues:
Total operating revenues	125	140
Georgia Power | Fuel
Operating Expenses:
Less Gross Gas Costs	419	313
Georgia Power | Purchased power
Operating Expenses:
Less Gross Gas Costs	150	144
Georgia Power | Purchased power, affiliates
Operating Expenses:
Less Gross Gas Costs	$ 206	$ 136

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Condensed Statements of Comprehensive Income (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net income	$ 991	$ 1,107
Qualifying hedges:
Changes in fair value, net of tax	19	(30)
Reclassification adjustment for amounts included in net income, net of tax	20	55
Total other comprehensive income	42	28
Comprehensive Income	1,033	1,135
Georgia Power
Net income	385	351
Qualifying hedges:
Changes in fair value, net of tax	9	0
Reclassification adjustment for amounts included in net income, net of tax	1	2
Total other comprehensive income	10	2
Comprehensive Income	$ 395	$ 353

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Condensed Statements of Comprehensive Income (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Changes in fair value, tax	$ 8	$ (10)
Qualifying hedges, reclassification adjustment, tax	6	18
Georgia Power
Changes in fair value, tax	3	0
Qualifying hedges, reclassification adjustment, tax	$ 1	$ 0

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Condensed Statements of Cash Flows (Unaudited) - GPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Pension, postretirement, and other employee benefits	(123)	(78)
Settlement of asset retirement obligations	(87)	(109)
Storm damage accruals	52	54
Retail fuel cost under recovery – long-term	(130)	0
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Accrued compensation	(470)	(417)
-Accrued interest	(128)	(90)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Property additions	(1,419)	(1,678)
Nuclear decommissioning trust fund purchases	(294)	(550)
Nuclear decommissioning trust fund sales	289	546
Cost of removal, net of salvage	(227)	(85)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Financing Activities:
Increase in notes payable	137	182
Proceeds —
Short-term borrowings	850	325
Redemptions and repurchases —
Payment of common stock dividends	(702)	(678)
Other financing activities	(115)	(117)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Noncash transactions —
Accrued property additions at year-end	863	872
Georgia Power
Operating Activities:
Net income (loss)	385	351
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	397	384
Deferred income taxes	(6)	(86)
Pension, postretirement, and other employee benefits	(63)	(43)
Settlement of asset retirement obligations	(41)	(49)
Storm damage accruals	53	53
Retail fuel cost under recovery – long-term	(84)	0
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Other, net	(85)	(19)
Changes in certain current assets and liabilities —
-Receivables	0	176
-Prepaid income taxes	(36)	0
-Other current assets	22	4
-Accounts payable	39	(74)
-Accrued taxes	(78)	(110)
-Accrued compensation	(79)	(68)
-Accrued interest	(43)	(34)
-Other current liabilities	(20)	(44)
Net cash provided from operating activities	361	489
Investing Activities:
Property additions	(749)	(775)
Nuclear decommissioning trust fund purchases	(221)	(241)
Nuclear decommissioning trust fund sales	217	236
Cost of removal, net of salvage	(140)	(40)
Change in construction payables	14	(103)
Proceeds from dispositions	56	1
Other investing activities	14	9
Net cash used for investing activities	(809)	(913)
Financing Activities:
Increase in notes payable	410	145
Proceeds —
Senior notes	0	750
Short-term borrowings	450	0
Redemptions and repurchases —
Senior notes	(400)	(325)
FFB loan	(24)	(25)
Capital contributions from parent company	445	330
Payment of common stock dividends	(423)	(412)
Other financing activities	(17)	(19)
Net cash provided from (used for) financing activities	441	444
Net Change in Cash, Cash Equivalents, and Restricted Cash	(7)	20
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	33	9
Cash, Cash Equivalents, and Restricted Cash at End of Period	26	29
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	139	128
Noncash transactions —
Accrued property additions at year-end	459	445
Right-of-use assets obtained under operating leases	$ 1	$ 3

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Condensed Statements of Cash Flows (Unaudited) - GPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net cash paid for capitalized interest	$ 23	$ 21
Georgia Power
Net cash paid for capitalized interest	$ 16	$ 15

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Condensed Balance Sheets (Unaudited) - GPC - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Unbilled revenues	638	711
Other accounts and notes	509	523
Fossil fuel for generation	411	450
Materials and supplies	1,571	1,543
Regulatory assets – asset retirement obligations	241	219
Assets from risk management activities	405	151
Other regulatory assets	576	653
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Nuclear fuel, at amortized cost	839	824
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	2,403	2,542
Equity investments in unconsolidated subsidiaries	1,293	1,282
Miscellaneous property and investments	633	653
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693	1,701
Deferred charges related to income taxes	833	824
Prepaid pension costs	1,772	1,657
Regulatory assets – asset retirement obligations, deferred	5,683	5,466
Other regulatory assets, deferred	5,372	5,577
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Notes payable	2,330	1,440
Accounts payable —
Customer deposits	454	479
Accrued interest	404	533
Accrued compensation	574	1,070
Operating lease obligations	245	250
Asset retirement obligations	695	697
Other regulatory liabilities	711	563
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Deferred credits related to income taxes	5,365	5,401
Accumulated deferred ITCs	2,196	2,216
Employee benefit obligations	1,526	1,550
Operating lease obligations, deferred	1,521	1,503
Asset retirement obligations, deferred	11,016	10,990
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Common Stockholder's Equity (See accompanying statements)	32,629	32,276
Total Liabilities and Stockholders' Equity	128,639	127,534
Georgia Power
Current Assets:
Cash and cash equivalents	26	33
Receivables —
Customer accounts	561	547
Unbilled revenues	216	231
Joint owner accounts	60	116
Affiliated	12	25
Other accounts and notes	35	44
Fossil fuel for generation	231	248
Materials and supplies	681	670
Regulatory assets – storm damage	4	48
Regulatory assets – asset retirement obligations	200	178
Assets from risk management activities	162	48
Other regulatory assets	248	241
Other current assets	124	130
Total current assets	2,560	2,559
Property, Plant, and Equipment:
In service	41,592	41,332
Less: Accumulated depreciation	13,029	12,854
Plant in service, net of depreciation	28,563	28,478
Nuclear fuel, at amortized cost	593	577
Construction work in progress	7,086	6,688
Total property, plant, and equipment	36,242	35,743
Other Property and Investments:
Nuclear decommissioning trusts, at fair value	1,146	1,217
Equity investments in unconsolidated subsidiaries	51	50
Miscellaneous property and investments	74	69
Total other property and investments	1,271	1,336
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,120	1,157
Deferred charges related to income taxes	557	550
Prepaid pension costs	608	563
Deferred under recovered fuel clause revenues	494	410
Regulatory assets – asset retirement obligations, deferred	3,781	3,688
Other regulatory assets, deferred	2,067	1,964
Other deferred charges and assets	506	491
Total deferred charges and other assets	9,133	8,823
Total Assets	49,206	48,461
Current Liabilities:
Securities due within one year	275	675
Notes payable	860	0
Accounts payable —
Affiliated	548	757
Other	873	702
Customer deposits	257	259
Accrued taxes	196	335
Accrued interest	93	136
Accrued compensation	124	232
Operating lease obligations	156	156
Asset retirement obligations	314	317
Other regulatory liabilities	336	280
Other current liabilities	292	254
Total current liabilities	4,324	4,103
Long-term Debt	13,088	13,109
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	3,155	3,019
Deferred credits related to income taxes	2,303	2,321
Accumulated deferred ITCs	326	328
Employee benefit obligations	390	402
Operating lease obligations, deferred	989	999
Asset retirement obligations, deferred	6,526	6,507
Other deferred credits and liabilities	456	439
Total deferred credits and other liabilities	14,145	14,015
Total Liabilities	31,557	31,227
Common Stockholder's Equity (See accompanying statements)	17,649	17,234
Total Liabilities and Stockholders' Equity	$ 49,206	$ 48,461

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Condensed Statements of Common Stockholders' Equity (Unaudited) - GPC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Georgia Power	Georgia Power Common Stock	Georgia Power Paid-In Capital	Georgia Power Retained Earnings (Accumulated Deficit)	Georgia Power Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020		1,058					9
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 16,501	$ 398	$ 12,361	$ 3,789	$ (47)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,107					351			351
Capital contributions from parent company						332		332
Other comprehensive income (loss)	28				28	2				2
Cash dividends on common stock	(678)			(678)		(412)			(412)
Ending balance (in shares) at Mar. 31, 2021		1,060					9
Ending balance at Mar. 31, 2021	33,068	$ 5,273	11,854	11,768	(367)	16,774	$ 398	12,693	3,728	(45)
Beginning balance (in shares) at Dec. 31, 2021		1,061					9
Beginning balance at Dec. 31, 2021	32,276	$ 5,279	11,950	10,929	(237)	17,234	$ 398	14,153	2,724	(41)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	991					385			385
Capital contributions from parent company						443		443
Other comprehensive income (loss)	42				42	10				10
Cash dividends on common stock	(702)			(702)		(423)			(423)
Ending balance (in shares) at Mar. 31, 2022		1,064					9
Ending balance at Mar. 31, 2022	$ 32,629	$ 5,286	$ 11,994	$ 11,261	$ (195)	$ 17,649	$ 398	$ 14,596	$ 2,686	$ (31)

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Condensed Statements of Common Stockholders' Equity (Unaudited) - GPC (Parenthetical) - $ / shares	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Statement of Stockholders' Equity [Abstract]
Cash dividends (in dollars per share)	$ 0.66	$ 0.64

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Condensed Statements of Income and Comprehensive Income (Unaudited) - MPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Interest expense, net of amounts capitalized	(462)	(450)
Other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Consolidated Net Income	991	1,107
Retail electric revenues
Operating Revenues:
Total operating revenues	3,613	3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
Mississippi Power
Operating Revenues:
Total operating revenues	335	307
Operating Expenses:
Other operations and maintenance	76	68
Depreciation and amortization	45	47
Taxes other than income taxes	29	31
Total operating expenses	282	252
Operating Income	53	55
Other Income and (Expense):
Interest expense, net of amounts capitalized	(13)	(14)
Other income (expense), net	10	8
Total other income and (expense)	(3)	(6)
Earnings Before Income Taxes	50	49
Income taxes (benefit)	8	4
Consolidated Net Income	42	45
Mississippi Power | Retail electric revenues
Operating Revenues:
Total operating revenues	217	204
Mississippi Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	68	63
Mississippi Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	42	33
Mississippi Power | Other revenues
Operating Revenues:
Total operating revenues	8	7
Mississippi Power | Fuel and purchased power
Operating Expenses:
Less Gross Gas Costs	$ 132	$ 106

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Condensed Statements of Cash Flows (Unaudited) - MPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Retail fuel cost over recovery	0	(53)
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Accrued compensation	(470)	(417)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Property additions	(1,419)	(1,678)
Construction payables	23	(116)
Payments pursuant to LTSAs	(37)	(60)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Financing Activities:
Increase in notes payable	137	182
Payment of common stock dividends	(702)	(678)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Noncash transactions —
Accrued property additions at year-end	863	872
Mississippi Power
Operating Activities:
Net income (loss)	42	45
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	55	53
Deferred income taxes	(5)	4
Other, net	17	(14)
Changes in certain current assets and liabilities —
-Receivables	(7)	7
-Retail fuel cost over recovery	(11)	0
-Other current assets	(11)	1
-Accounts payable	(9)	(30)
-Accrued taxes	(63)	(75)
-Accrued compensation	(18)	(16)
-Other current liabilities	(6)	(13)
Net cash provided from operating activities	(16)	(38)
Investing Activities:
Property additions	(45)	(45)
Construction payables	(8)	(8)
Payments pursuant to LTSAs	(8)	(7)
Other investing activities	(7)	(7)
Net cash used for investing activities	(68)	(67)
Financing Activities:
Increase in notes payable	25	29
Capital contributions from parent company	50	100
Payment of common stock dividends	(43)	(39)
Net cash provided from (used for) financing activities	32	90
Net Change in Cash, Cash Equivalents, and Restricted Cash	(52)	(15)
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	61	39
Cash, Cash Equivalents, and Restricted Cash at End of Period	9	24
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	22	16
Noncash transactions —
Accrued property additions at year-end	$ 17	$ 26

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Condensed Statements of Cash Flows (Unaudited) - MPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net cash paid for capitalized interest	$ 23	$ 21

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Condensed Balance Sheets (Unaudited) - MPC - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Unbilled revenues	638	711
Other accounts and notes	509	523
Fossil fuel for generation	411	450
Materials and supplies	1,571	1,543
Assets from risk management activities	405	151
Other regulatory assets	576	653
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Deferred charges related to income taxes	833	824
Regulatory assets – asset retirement obligations, deferred	5,683	5,466
Other regulatory assets, deferred	5,372	5,577
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Notes payable	2,330	1,440
Accounts payable —
Accrued compensation	574	1,070
Asset retirement obligations	695	697
Other regulatory liabilities	711	563
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Deferred credits related to income taxes	5,365	5,401
Employee benefit obligations	1,526	1,550
Asset retirement obligations, deferred	11,016	10,990
Other cost of removal obligations	2,030	2,103
Other regulatory liabilities, deferred	526	485
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Total Liabilities and Stockholders' Equity	128,639	127,534
Mississippi Power
Current Assets:
Cash and cash equivalents	9	61
Receivables —
Customer accounts	65	37
Unbilled revenues	36	34
Affiliated	17	29
Other accounts and notes	30	28
Fossil fuel for generation	30	28
Materials and supplies	72	70
Assets from risk management activities	94	28
Other regulatory assets	61	54
Other current assets	10	13
Total current assets	424	382
Property, Plant, and Equipment:
In service	5,149	5,106
Less: Accumulated depreciation	1,626	1,591
Plant in service, net of depreciation	3,523	3,515
Construction work in progress	111	127
Total property, plant, and equipment	3,634	3,642
Other Property and Investments:
Total other property and investments	177	179
Deferred Charges and Other Assets:
Deferred charges related to income taxes	30	31
Prepaid pension costs	85	79
Regulatory assets – asset retirement obligations, deferred	235	232
Other regulatory assets, deferred	298	317
Accumulated deferred income taxes	115	118
Other deferred charges and assets	127	100
Total deferred charges and other assets	890	877
Total Assets	5,125	5,080
Current Liabilities:
Securities due within one year	1	1
Notes payable	25	0
Accounts payable —
Affiliated	58	81
Other	53	47
Accrued taxes	56	120
Accrued compensation	20	36
Asset retirement obligations	28	30
Other regulatory liabilities	120	59
Other current liabilities	55	65
Total current liabilities	416	439
Long-term Debt	1,510	1,510
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	462	464
Deferred credits related to income taxes	269	269
Employee benefit obligations	88	88
Asset retirement obligations, deferred	161	160
Other cost of removal obligations	194	195
Other regulatory liabilities, deferred	84	64
Other deferred credits and liabilities	24	24
Total deferred credits and other liabilities	1,282	1,264
Total Liabilities	3,208	3,213
Total common stockholders' equity	1,917	1,867
Total Liabilities and Stockholders' Equity	$ 5,125	$ 5,080

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Condensed Statements of Common Stockholders' Equity (Unaudited) - MPC - USD ($) shares in Millions, $ in Millions	Total	Common Stock	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Mississippi Power	Mississippi Power Common Stock	Mississippi Power Paid-In Capital	Mississippi Power Retained Earnings (Accumulated Deficit)	Mississippi Power Accumulated Other Comprehensive Income (Loss)
Beginning balance (in shares) at Dec. 31, 2020		1,058					1
Beginning balance at Dec. 31, 2020	$ 32,234	$ 5,268	$ 11,834	$ 11,311	$ (395)	$ 1,742	$ 38	$ 4,460	$ (2,754)	$ (2)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,135					45			45
Capital contributions from parent company						100		100
Cash dividends on common stock	(678)			(678)		(39)			(39)
Ending balance (in shares) at Mar. 31, 2021		1,060					1
Ending balance at Mar. 31, 2021	33,068	$ 5,273	11,854	11,768	(367)	1,848	$ 38	4,560	(2,748)	(2)
Beginning balance (in shares) at Dec. 31, 2021		1,061					1
Beginning balance at Dec. 31, 2021	32,276	$ 5,279	11,950	10,929	(237)	1,867	$ 38	4,582	(2,753)	0
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,032					42			42
Capital contributions from parent company						51		51
Cash dividends on common stock	(702)			(702)		(43)			(43)
Ending balance (in shares) at Mar. 31, 2022		1,064					1
Ending balance at Mar. 31, 2022	$ 32,629	$ 5,286	$ 11,994	$ 11,261	$ (195)	$ 1,917	$ 38	$ 4,633	$ (2,754)	$ 0

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Condensed Consolidated Statements of Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Gain on dispositions, net	(23)	(44)
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Interest expense, net of amounts capitalized	(462)	(450)
Other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Consolidated Net Income	991	1,107
Net loss attributable to noncontrolling interests	(45)	(32)
Retail electric revenues
Operating Revenues:
Total operating revenues	3,613	3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
Fuel
Operating Expenses:
Less Gross Gas Costs	1,111	848
Purchased power
Operating Expenses:
Less Gross Gas Costs	232	207
Southern Power
Operating Revenues:
Total operating revenues	539	440
Operating Expenses:
Other operations and maintenance	105	101
Depreciation and amortization	120	119
Taxes other than income taxes	13	12
Gain on dispositions, net	(2)	(39)
Total operating expenses	489	354
Operating Income	50	86
Other Income and (Expense):
Interest expense, net of amounts capitalized	(37)	(38)
Other income (expense), net	2	7
Total other income and (expense)	(35)	(31)
Earnings Before Income Taxes	15	55
Income taxes (benefit)	(12)	(10)
Consolidated Net Income	27	65
Net loss attributable to noncontrolling interests	(45)	(32)
Net Income	72	97
Southern Power | Wholesale revenues, non-affiliates
Operating Revenues:
Total operating revenues	426	355
Southern Power | Wholesale revenues, affiliates
Operating Revenues:
Total operating revenues	105	81
Southern Power | Other revenues
Operating Revenues:
Total operating revenues	8	4
Southern Power | Fuel
Operating Expenses:
Less Gross Gas Costs	232	141
Southern Power | Purchased power
Operating Expenses:
Less Gross Gas Costs	$ 21	$ 20

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net income	$ 991	$ 1,107
Qualifying hedges:
Changes in fair value, net of tax	19	(30)
Reclassification adjustment for amounts included in net income, net of tax	20	55
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	3	3
Total other comprehensive income	42	28
Comprehensive Income	1,033	1,135
Comprehensive loss attributable to noncontrolling interests	(45)	(32)
Comprehensive Income	1,074	1,163
Southern Power
Net income	27	65
Qualifying hedges:
Changes in fair value, net of tax	(17)	(33)
Reclassification adjustment for amounts included in net income, net of tax	22	48
Pension and other postretirement benefit plans:
Reclassification adjustment for amounts included in net income, net of tax	0	1
Total other comprehensive income	5	16
Comprehensive Income	32	81
Comprehensive loss attributable to noncontrolling interests	(45)	(32)
Comprehensive Income	$ 77	$ 113

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Changes in fair value, tax	$ 8	$ (10)
Qualifying hedges, reclassification adjustment, tax	6	18
Reclassification adjustment for amounts included in net income, tax	1	1
Southern Power
Changes in fair value, tax	(6)	(11)
Qualifying hedges, reclassification adjustment, tax	7	15
Reclassification adjustment for amounts included in net income, tax	$ 0	$ 0

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Gain on dispositions, net	(20)	(41)
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(1,419)	(1,678)
Payments pursuant to LTSAs	(37)	(60)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Financing Activities:
Increase in notes payable	137	182
Proceeds —
Capital contributions from noncontrolling interests	73	313
Distributions to noncontrolling interests	(97)	(46)
Payment of common stock dividends	(702)	(678)
Other financing activities	(115)	(117)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Income taxes, net	(8)	(51)
Noncash transactions —
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Accrued property additions at year-end	863	872
Reassessment of right-of-use assets under operating leases	40	0
Southern Power
Operating Activities:
Net income (loss)	27	65
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	126	125
Deferred income taxes	12	(8)
Amortization of investment tax credits	(15)	(15)
Gain on dispositions, net	(2)	(39)
Other, net	(3)	(4)
Changes in certain current assets and liabilities —
-Receivables	11	23
-Prepaid income taxes	(8)	16
-Other current assets	0	3
-Accounts payable	(21)	19
-Accrued taxes	7	5
-Other current liabilities	(17)	(3)
Net cash provided from operating activities	117	187
Investing Activities:
Business acquisitions, net of cash acquired	0	(345)
Property additions	(19)	(147)
Proceeds from dispositions	29	17
Change in construction payables	(31)	(7)
Payments pursuant to LTSAs	(15)	(27)
Other investing activities	(1)	5
Net cash used for investing activities	(37)	(504)
Financing Activities:
Increase (decrease) in notes payable, net	(3)
Increase in notes payable		140
Proceeds —
Senior notes	0	400
Return of capital to parent company	0	(271)
Capital contributions from noncontrolling interests	73	313
Distributions to noncontrolling interests	(97)	(46)
Payment of common stock dividends	(49)	(51)
Other financing activities	0	(7)
Net cash provided from (used for) financing activities	(76)	478
Net Change in Cash, Cash Equivalents, and Restricted Cash	4	161
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	135	182
Cash, Cash Equivalents, and Restricted Cash at End of Period	139	343
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	29	26
Income taxes, net	(8)	(2)
Noncash transactions —
Contributions from noncontrolling interests	0	89
Contributions of wind turbine equipment	0	82
Accrued property additions at year-end	46	60
Right-of-use assets obtained under operating leases	0	65
Reassessment of right-of-use assets under operating leases	$ 40	$ 0

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Condensed Consolidated Statements of Cash Flows (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net cash paid for capitalized interest	$ 23	$ 21
Southern Power
Net cash paid for capitalized interest	$ 0	$ 1

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Condensed Consolidated Balance Sheets (Unaudited) - SPC - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Other accounts and notes	509	523
Materials and supplies	1,571	1,543
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Equity investments in unconsolidated subsidiaries	1,293	1,282
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693	1,701
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Notes payable	2,330	1,440
Accounts payable —
Accrued interest	404	533
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Accumulated deferred ITCs	2,196	2,216
Operating lease obligations, deferred	1,521	1,503
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Total Stockholders' Equity (See accompanying statements)	32,629	32,276
Total Liabilities and Stockholders' Equity	128,639	127,534
Southern Power
Current Assets:
Cash and cash equivalents	130	107
Receivables —
Customer accounts	160	139
Affiliated	26	51
Other accounts and notes	21	29
Materials and supplies	108	106
Prepaid income taxes	468	27
Other current assets	49	46
Total current assets	962	505
Property, Plant, and Equipment:
In service	14,594	14,585
Less: Accumulated depreciation	3,341	3,241
Plant in service, net of depreciation	11,253	11,344
Construction work in progress	49	45
Total property, plant, and equipment	11,302	11,389
Other Property and Investments:
Intangible assets, net of amortization	278	282
Equity investments in unconsolidated subsidiaries	56	86
Net investment in sales-type leases	159	161
Total other property and investments	493	529
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	517	479
Prepaid LTSAs	219	210
Income taxes receivable, non-current	23	20
Other deferred charges and assets	250	258
Total deferred charges and other assets	1,009	967
Total Assets	13,766	13,390
Current Liabilities:
Securities due within one year	666	679
Notes payable	208	211
Accounts payable —
Affiliated	82	92
Other	67	85
Accrued taxes	21	14
Accrued interest	32	32
Other current liabilities	121	140
Total current liabilities	1,197	1,253
Long-term Debt	2,999	3,009
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	661	215
Accumulated deferred ITCs	1,600	1,614
Operating lease obligations, deferred	535	497
Other deferred credits and liabilities	218	204
Total deferred credits and other liabilities	3,014	2,530
Total Liabilities	7,210	6,792
Total Stockholders' Equity (See accompanying statements)	6,556	6,598
Total Liabilities and Stockholders' Equity	$ 13,766	$ 13,390

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Condensed Consolidated Balance Sheets (Unaudited) - SPC (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Other intangible assets, amortization	$ 317	$ 307
SOUTHERN POWER CO
Other intangible assets, amortization	$ 114	$ 109

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - SPC - USD ($) $ in Millions	Total	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	Noncontrolling Interests	Southern Power	Southern Power Total Common Stockholders' Equity	Southern Power Paid-In Capital	Southern Power Retained Earnings (Accumulated Deficit)	Southern Power Accumulated Other Comprehensive Income (Loss)	Southern Power Noncontrolling Interests
Beginning balance at Dec. 31, 2020	$ 32,234	$ 11,834	$ 11,311	$ (395)	$ 4,262	$ 6,631	$ 2,369	$ 914	$ 1,522	$ (67)	$ 4,262
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,107					65	97		97		(32)
Return of capital to parent company						(271)	(271)	(271)
Other comprehensive income (loss)	28			28		16	16			16
Cash dividends on common stock	(678)		(678)			(51)	(51)		(51)
Capital contributions from noncontrolling interests	403				403	403					403
Distributions to noncontrolling interests	(46)				(46)	(46)					(46)
Other	1	2			(1)	(3)	(2)	(2)	1	(1)	(1)
Ending balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	4,586	6,744	2,158	641	1,569	(52)	4,586
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	4,402	6,598	2,196	638	1,585	(27)	4,402
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	991					27	72		72		(45)
Other comprehensive income (loss)	42			42		5	5			5
Cash dividends on common stock	(702)		(702)			(49)	(49)		(49)
Capital contributions from noncontrolling interests	73				73	73					73
Distributions to noncontrolling interests	(98)				(98)	(98)					(98)
Other	7	7	2
Ending balance at Mar. 31, 2022	$ 32,629	$ 11,994	$ 11,261	$ (195)	$ 4,332	$ 6,556	$ 2,224	$ 638	$ 1,608	$ (22)	$ 4,332

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Condensed Consolidated Statements of Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Revenues:
Total operating revenues	$ 6,648	$ 5,910
Operating Expenses:
Other operations and maintenance	1,516	1,372
Depreciation and amortization	892	871
Taxes other than income taxes	372	345
Total operating expenses	5,264	4,312
Operating Income	1,384	1,598
Other Income and (Expense):
Earnings from equity method investments	46	45
Interest expense, net of amounts capitalized	(462)	(450)
Other income (expense), net	145	58
Total other income and (expense)	(220)	(301)
Earnings Before Income Taxes	1,164	1,297
Income taxes (benefit)	173	190
Consolidated Net Income	991	1,107
Retail electric revenues
Operating Revenues:
Total operating revenues	3,613	3,342
Wholesale Electric
Operating Revenues:
Total operating revenues	664	545
Other electric revenues
Operating Revenues:
Total operating revenues	177	170
Natural Gas
Operating Revenues:
Total operating revenues	2,058	1,694
Natural gas
Operating Expenses:
Less Gross Gas Costs	1,095	583
Alternative revenue programs
Operating Revenues:
Total operating revenues	0	2
Other revenues
Operating Revenues:
Total operating revenues	136	159
Operating Expenses:
Less Gross Gas Costs	69	82
SOUTHERN Co GAS
Operating Revenues:
Total operating revenues	$ 2,058	$ 1,694
Operating Expenses:
Cost, Product and Service [Extensible Enumeration]	Natural gas	Natural gas
Other operations and maintenance	$ 305	$ 299
Depreciation and amortization	137	130
Taxes other than income taxes	100	81
Total operating expenses	1,637	1,093
Operating Income	421	601
Other Income and (Expense):
Earnings from equity method investments	40	41
Interest expense, net of amounts capitalized	(61)	(60)
Other income (expense), net	16	(63)
Total other income and (expense)	(5)	(82)
Earnings Before Income Taxes	416	519
Income taxes (benefit)	97	121
Consolidated Net Income	319	398
SOUTHERN Co GAS | Natural gas
Operating Revenues:
Total operating revenues	2,058	1,692
Operating Expenses:
Less Gross Gas Costs	1,095	583
SOUTHERN Co GAS | Alternative revenue programs
Operating Revenues:
Total operating revenues	$ 0	$ 2

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Condensed Consolidated Statements of Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
SOUTHERN Co GAS
Revenue taxes collected	$ 71	$ 54

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net income	$ 991	$ 1,107
Qualifying hedges:
Changes in fair value, net of tax	19	(30)
Reclassification adjustment for amounts included in net income, net of tax	20	55
Total other comprehensive income	42	28
Comprehensive Income	1,033	1,135
SOUTHERN Co GAS
Net income	319	398
Qualifying hedges:
Changes in fair value, net of tax	26	1
Reclassification adjustment for amounts included in net income, net of tax	(6)	3
Total other comprehensive income	20	4
Comprehensive Income	$ 339	$ 402

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Condensed Consolidated Statements of Comprehensive Income (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Changes in fair value, tax	$ 8	$ (10)
Qualifying hedges, reclassification adjustment, tax	6	18
SOUTHERN Co GAS
Changes in fair value, tax	10	0
Qualifying hedges, reclassification adjustment, tax	$ (2)	$ 1

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Operating Activities:
Net income (loss)	$ 991	$ 1,107
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	989	964
Deferred income taxes	40	140
Natural gas cost under recovery – long-term	162	(185)
Other, net	7	114
Changes in certain current assets and liabilities —
-Receivables	(217)	308
-Natural gas for sale, net of temporary LIFO liquidation	450	456
-Natural gas cost under recovery	(40)	(487)
-Other current assets	87	90
-Accounts payable	132	(216)
-Accrued taxes	(58)	(212)
-Other current liabilities	35	(63)
Net cash provided from operating activities	1,592	1,242
Investing Activities:
Property additions	(1,419)	(1,678)
Cost of removal, net of salvage	(227)	(85)
Change in construction payables, net	23	(116)
Other investing activities	110	45
Net cash used for investing activities	(1,555)	(2,243)
Proceeds —
Short-term borrowings	850	325
Redemptions and repurchases —
Short-term borrowings	(100)	(25)
Payment of common stock dividends	(702)	(678)
Net cash provided from (used for) financing activities	(193)	1,734
Net Change in Cash, Cash Equivalents, and Restricted Cash	(156)	733
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	1,829	1,068
Cash, Cash Equivalents, and Restricted Cash at End of Period	1,673	1,801
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	515	519
Income taxes, net	(8)	(51)
Noncash transactions —
Accrued property additions at year-end	863	872
SOUTHERN Co GAS
Operating Activities:
Net income (loss)	319	398
Adjustments to reconcile net income to net cash provided from operating activities —
Depreciation and amortization, total	137	130
Deferred income taxes	5	160
Mark-to-market adjustments	(38)	64
Natural gas cost under recovery – long-term	162	(185)
Other, net	41	5
Changes in certain current assets and liabilities —
-Receivables	(115)	74
-Natural gas for sale, net of temporary LIFO liquidation	450	456
-Prepaid income taxes	34	(51)
-Natural gas cost under recovery	(40)	(487)
-Other current assets	39	17
-Accounts payable	(23)	(7)
-Accrued taxes	54	10
-Other current liabilities	(1)	(34)
Net cash provided from operating activities	1,024	550
Investing Activities:
Property additions	(247)	(251)
Cost of removal, net of salvage	(20)	(16)
Change in construction payables, net	(5)	(47)
Other investing activities	1	6
Net cash used for investing activities	(271)	(308)
Financing Activities:
Increase (decrease) in notes payable, net	(577)	(127)
Proceeds —
Short-term borrowings	0	300
Redemptions and repurchases —
Short-term borrowings	(100)	0
Medium-term notes	0	(30)
Capital contributions from parent company	39	39
Payment of common stock dividends	(130)	(132)
Net cash provided from (used for) financing activities	(768)	50
Net Change in Cash, Cash Equivalents, and Restricted Cash	(15)	292
Cash, Cash Equivalents, and Restricted Cash at Beginning of Period	48	19
Cash, Cash Equivalents, and Restricted Cash at End of Period	33	311
Supplemental Cash Flow Information:
Interest, net of amounts capitalized	55	52
Income taxes, net	0	(1)
Noncash transactions —
Accrued property additions at year-end	$ 107	$ 95

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Condensed Consolidated Statements of Cash Flows (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Net cash paid for capitalized interest	$ 23	$ 21
SOUTHERN Co GAS
Net cash paid for capitalized interest	$ 2	$ 2

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Condensed Consolidated Balance Sheets (Unaudited) - GAS - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Current Assets:
Cash and cash equivalents	$ 1,662	$ 1,798
Receivables —
Customer accounts	2,006	1,806
Unbilled revenues	638	711
Other accounts and notes	509	523
Accumulated provision for uncollectible accounts	(89)	(78)
Natural gas for sale	121	362
Prepaid expenses	739	330
Assets from risk management activities, net of collateral	405	151
Natural gas cost under recovery	306	266
Other regulatory assets	576	653
Other current assets	201	231
Total current assets	9,297	8,965
Property, Plant, and Equipment:
In service	116,259	115,592
Less: Accumulated depreciation	34,645	34,079
Plant in service, net of depreciation	81,614	81,513
Construction work in progress	9,337	8,771
Total property, plant, and equipment	91,790	91,108
Other Property and Investments:
Goodwill	5,280	5,280
Equity investments in unconsolidated subsidiaries	1,293	1,282
Other intangible assets, net of amortization	435	445
Miscellaneous property and investments	633	653
Total other property and investments	10,044	10,202
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	1,693	1,701
Prepaid pension costs	1,772	1,657
Other regulatory assets, deferred	5,372	5,577
Other deferred charges and assets	1,898	1,776
Total deferred charges and other assets	17,508	17,259
Total Assets	128,639	127,534
Current Liabilities:
Securities due within one year	1,193	2,157
Notes payable	2,330	1,440
Accounts payable —
Customer deposits	454	479
Accrued interest	404	533
Accrued compensation	574	1,070
Other regulatory liabilities	711	563
Other current liabilities	1,105	872
Total current liabilities	10,434	10,921
Long-term Debt	50,633	50,120
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	9,506	8,862
Deferred credits related to income taxes	5,365	5,401
Employee benefit obligations	1,526	1,550
Operating lease obligations, deferred	1,521	1,503
Other cost of removal obligations	2,030	2,103
Other deferred credits and liabilities	966	816
Total deferred credits and other liabilities	34,652	33,926
Total Liabilities	95,719	94,967
Common Stockholder's Equity (See accompanying statements)	32,629	32,276
Total Liabilities and Stockholders' Equity	128,639	127,534
SOUTHERN Co GAS
Current Assets:
Cash and cash equivalents	31	45
Receivables —
Customer accounts	603	462
Unbilled revenues	245	278
Other accounts and notes	52	49
Accumulated provision for uncollectible accounts	(51)	(39)
Natural gas for sale	121	362
Prepaid expenses	88	114
Assets from risk management activities, net of collateral	53	33
Natural gas cost under recovery	306	266
Other regulatory assets	104	136
Other current assets	47	49
Total current assets	1,599	1,755
Property, Plant, and Equipment:
In service	19,035	18,880
Less: Accumulated depreciation	5,159	5,067
Plant in service, net of depreciation	13,876	13,813
Construction work in progress	768	684
Total property, plant, and equipment	14,644	14,497
Other Property and Investments:
Goodwill	5,015	5,015
Equity investments in unconsolidated subsidiaries	1,178	1,173
Other intangible assets, net of amortization	34	37
Miscellaneous property and investments	19	19
Total other property and investments	6,246	6,244
Deferred Charges and Other Assets:
Operating lease right-of-use assets, net of amortization	67	70
Prepaid pension costs	183	175
Other regulatory assets, deferred	508	689
Other deferred charges and assets	130	130
Total deferred charges and other assets	888	1,064
Total Assets	23,377	23,560
Current Liabilities:
Securities due within one year	46	47
Notes payable	532	1,209
Accounts payable —
Affiliated	40	58
Other	349	361
Customer deposits	72	95
Accrued taxes	191	124
Accrued interest	68	59
Accrued compensation	66	110
Temporary LIFO liquidation	209	0
Other regulatory liabilities	72	8
Other current liabilities	140	155
Total current liabilities	1,785	2,226
Long-term Debt	6,814	6,855
Deferred Credits and Other Liabilities:
Accumulated deferred income taxes	1,568	1,555
Deferred credits related to income taxes	808	816
Employee benefit obligations	168	176
Operating lease obligations, deferred	58	59
Other cost of removal obligations	1,692	1,683
Accrued environmental remediation	189	197
Other deferred credits and liabilities	120	77
Total deferred credits and other liabilities	4,603	4,563
Total Liabilities	13,202	13,644
Common Stockholder's Equity (See accompanying statements)	10,175	9,916
Total Liabilities and Stockholders' Equity	$ 23,377	$ 23,560

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Condensed Consolidated Balance Sheets (Unaudited) - GAS (Parenthetical) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Other intangible assets, amortization	$ 317	$ 307
SOUTHERN Co GAS
Other intangible assets, amortization	$ 148	$ 145

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Condensed Consolidated Statements of Stockholders' Equity (Unaudited) - GAS - USD ($) $ in Millions	Total	Paid-In Capital	Retained Earnings (Accumulated Deficit)	Accumulated Other Comprehensive Income (Loss)	SOUTHERN Co GAS	SOUTHERN Co GAS Paid-In Capital	SOUTHERN Co GAS Retained Earnings (Accumulated Deficit)	SOUTHERN Co GAS Accumulated Other Comprehensive Income (Loss)
Beginning balance at Dec. 31, 2020	$ 32,234	$ 11,834	$ 11,311	$ (395)	$ 9,767	$ 9,930	$ (141)	$ (22)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	1,107				398		398
Capital contributions from parent company					57	57
Other comprehensive income (loss)	28			28	4			4
Cash dividends on common stock	(678)		(678)		(132)		(132)
Ending balance at Mar. 31, 2021	33,068	11,854	11,768	(367)	10,094	9,987	125	(18)
Beginning balance at Dec. 31, 2021	32,276	11,950	10,929	(237)	9,916	10,024	(132)	24
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Net income	991				319		319
Capital contributions from parent company					50	50
Other comprehensive income (loss)	42			42	20			20
Cash dividends on common stock	(702)		(702)		(130)		(130)
Ending balance at Mar. 31, 2022	$ 32,629	$ 11,994	$ 11,261	$ (195)	$ 10,175	$ 10,074	$ 57	$ 44

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Introduction

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Introduction

INTRODUCTION

The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2021 have been derived from the audited financial statements of each Registrant. In the opinion of each Registrant's management, the information regarding such Registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended March 31, 2022 and 2021. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each Registrant believes that the disclosures regarding such Registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy and other factors, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year.

Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant.

Goodwill and Other Intangible Assets

Goodwill at March 31, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

Other intangible assets were as follows:

	At March 31, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(152)	$	60	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(114)		276		390		(109)		281
Other	11		(10)		1		11		(10)		1
Total other intangible assets subject to amortization	$	677	$	(317)	$	360	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	752	$	(317)	$	435	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(114)	$	276	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(132)	$	24	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(148)	$	34	$	182	$	(145)	$	37

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2022
	(in millions)
Southern Company(a)	$	10
Southern Power(b)	5
Southern Company Gas	3

(a)Includes $5 million recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Cash, Cash Equivalents, and Restricted Cash

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,662	$	1,798	$	130	$	107	$	31	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,673	$	1,829	$	139	$	135	$	33	$	48

(a)For Southern Power, restricted cash reflects $9 million and $10 million at March 31, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects restricted cash held as collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated.

Southern Company Gas recorded no material adjustments to natural gas inventories for either period presented. Nicor Gas' inventory decrement at March 31, 2022 is expected to be restored prior to year end.

Depreciation and Amortization

See Note 5 to the financial statements under "Depreciation and Amortization – Southern Power" in Item 8 of the Form 10-K for additional information.

Effective January 1, 2022, Southern Power revised the depreciable lives of its wind generating facilities from up to 30 years to up to 35 years. This revision resulted in an immaterial decrease in depreciation for the three months ended March 31, 2022 and is expected to result in an immaterial decrease in annual depreciation for 2022.

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Regulatory Matters

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Regulatory Matters

REGULATORY MATTERS

See Note 2 to the financial statements in Item 8 of the Form 10-K for additional information relating to regulatory matters.

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at March 31, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	12	$	16
Rate CNP PPA	Other regulatory assets, deferred	84		84
Retail Energy Cost Recovery(*)	Other regulatory assets, deferred	46		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	494	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	16	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	33		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	306	$	266
	Other regulatory assets, deferred	44		207
	Other regulatory liabilities, current	13		—

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Alabama Power

Certificate of Convenience and Necessity

On March 25, 2022, the FERC approved Alabama Power's acquisition of the Calhoun Generating Station, which is expected to be completed by September 30, 2022. The completion of the acquisition remains subject to approval by the Alabama PSC. The ultimate outcome of this matter cannot be determined at this time.

Georgia Power

Rate Plan

In 2020, the Georgia PSC denied a motion for reconsideration filed by the Sierra Club regarding the Georgia PSC's decision in the 2019 ARP allowing Georgia Power to recover compliance costs for CCR AROs. The Superior Court of Fulton County subsequently affirmed the Georgia PSC's decision and, in October 2021, the Georgia Court of Appeals affirmed the Superior Court of Fulton County's order. In December 2021, the Sierra Club filed a petition for writ of certiorari to the Georgia Supreme Court. The ultimate outcome of this matter cannot be determined at this time. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information regarding Georgia Power's AROs.

Integrated Resource Plan

In light of the ongoing supply chain challenges in the solar industry, Georgia Power amended the 970 MWs of utility-scale PPAs authorized in its 2019 Integrated Resource Plan to extend by one year the in-service dates for solar generation resources to the end of 2024.

Nuclear Construction

In 2009, the Georgia PSC certified construction of Plant Vogtle Units 3 and 4, in which Georgia Power holds a 45.7% ownership interest. In 2012, the NRC issued the related combined construction and operating licenses, which allowed full construction of the two AP1000 nuclear units (with electric generating capacity of approximately 1,100 MWs each) and related facilities to begin. Until March 2017, construction on Plant Vogtle Units 3 and 4 continued under the Vogtle 3 and 4 Agreement, which was a substantially fixed price agreement.

In connection with the EPC Contractor's bankruptcy filing in March 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into several transitional arrangements to allow construction to continue. In July 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, entered into the Vogtle Services Agreement, whereby Westinghouse provides facility design and engineering services, procurement and technical support, and staff augmentation on a time and materials cost basis. The Vogtle Services Agreement provides that it will continue until the start-up and testing of Plant Vogtle Units 3 and 4 are complete and electricity is generated and sold from both units. The Vogtle Services Agreement is terminable by the Vogtle Owners upon 30 days' written notice.

In October 2017, Georgia Power, acting for itself and as agent for the other Vogtle Owners, executed the Bechtel Agreement, a cost reimbursable plus fee arrangement, whereby Bechtel is reimbursed for actual costs plus a base fee and an at-risk fee, which is subject to adjustment based on Bechtel's performance against cost and schedule targets. Each Vogtle Owner is severally (not jointly) liable for its proportionate share, based on its ownership interest, of all amounts owed to Bechtel under the Bechtel Agreement. The Vogtle Owners may terminate the Bechtel Agreement at any time for their convenience, provided that the Vogtle Owners will be required to pay amounts related to work performed prior to the termination (including the applicable portion of the base fee), certain termination-related costs, and, at certain stages of the work, the applicable portion of the at-risk fee. Bechtel may terminate the Bechtel Agreement under certain circumstances, including certain Vogtle Owner suspensions of work, certain breaches of the Bechtel Agreement by the Vogtle Owners, Vogtle Owner insolvency, and certain other events.

See Note 8 to the financial statements under "Long-term Debt – DOE Loan Guarantee Borrowings" in Item 8 of the Form 10-K for information on the Amended and Restated Loan Guarantee Agreement, including applicable covenants, events of default, and mandatory prepayment events.

Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,294
Construction contingency estimate	107
Total project capital cost forecast(a)(b)	10,401
Net investment at March 31, 2022(b)	(8,715)
Remaining estimate to complete	$	1,686

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $440 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $377 million, of which $221 million had been accrued through March 31, 2022.

(b)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.

Georgia Power estimates that its financing costs for construction of Plant Vogtle Units 3 and 4 will total approximately $3.4 billion, of which $3.0 billion had been incurred through March 31, 2022.

As part of its ongoing processes, Southern Nuclear continues to evaluate cost and schedule forecasts on a regular basis to incorporate current information available, particularly in the areas of engineering support, commodity installation, system turnovers and related test results, and workforce statistics. Southern Nuclear establishes aggressive target values for monthly construction production and system turnover activities, which are reflected in the site work plans.

Since March 2020, the number of active COVID-19 cases at the site has fluctuated consistent with the surrounding area and impacted productivity levels and pace of activity completion, with the site experiencing peaks in the number of active cases in January 2021, August 2021, and January 2022. Georgia Power estimates the productivity impacts of the COVID-19 pandemic have consumed approximately three to four months of schedule margin previously embedded in the site work plan for Unit 3 and Unit 4. As of March 31, 2022, Georgia Power's proportionate share of the estimated incremental cost associated with COVID-19 mitigation actions and impacts on construction productivity is estimated to be between $160 million and $200 million and is included in the total project capital cost forecast. The continuing effects of the COVID-19 pandemic could further disrupt or delay construction and testing activities at Plant Vogtle Units 3 and 4.

Fuel load for Unit 3 is projected during the third quarter or the fourth quarter 2022 with an in-service date projected during the fourth quarter 2022 or the first quarter 2023. Unit 3's projected schedule primarily depends on improvements in overall construction productivity and production levels, the volume and completion of construction remediation work, completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, the pace of system and area turnovers, and the progression of startup and other testing. An in-service date during the third quarter or the fourth quarter 2023 for Unit 4 is projected. Unit 4's projected schedule primarily depends on overall construction productivity and production levels improving as well as appropriate levels of craft laborers, particularly electricians and pipefitters, being added and maintained. Any further delays could result in later in-service dates.

During the first quarter 2022, established construction contingency totaling $43 million was assigned to the base capital cost forecast for costs primarily associated with construction productivity, the pace of system turnovers, and support resources for Units 3 and 4.

As Unit 3 completes system turnover from construction and moves to testing and transition to operations, ongoing and potential future challenges include construction productivity, completion of construction remediation work,

completion of work packages, including inspection records, and other documentation necessary to submit the remaining ITAACs and begin fuel load, and final component and pre-operational tests. As Unit 4 progresses through construction and continues to transition into testing, ongoing and potential future challenges include the pace and quality of electrical installation; availability of craft and supervisory resources, including the temporary diversion of such resources to support Unit 3 construction efforts; the pace of work package closures and system turnovers; and the timeframe and duration of hot functional and other testing. As construction, including subcontract work, continues on both Units 3 and 4, ongoing or future challenges include management of contractors and vendors; subcontractor performance; supervision of craft labor and related productivity, particularly in the installation of electrical, mechanical, and instrumentation and controls commodities, ability to attract and retain craft labor, and/or related cost escalation; and procurement and related installation. New challenges may arise, particularly as Units 3 and 4 move into initial testing and start-up, which may result in required engineering changes or remediation related to plant systems, structures, or components (some of which are based on new technology that only within the last few years began initial operation in the global nuclear industry at this scale). The ongoing and potential future challenges described above may change the projected schedule and estimated cost.

There have been technical and procedural challenges to the construction and licensing of Plant Vogtle Units 3 and 4 at the federal and state level and additional challenges may arise. In addition, certain license amendment requests have been filed and approved or are pending before the NRC. Processes are in place that are designed to ensure compliance with the requirements specified in the Westinghouse Design Control Document and the combined construction and operating licenses, including inspections by Southern Nuclear and the NRC that occur throughout construction. In connection with the additional construction remediation work described above, Southern Nuclear reviewed the project's construction quality programs and, where needed, is implementing improvement plans consistent with these processes. On March 25, 2022, the NRC completed its follow-up inspection related to the November 2021 final significance report on its special inspection to review the root cause of this additional construction remediation work and the corresponding corrective action plans. The NRC closed the two white findings identified in November 2021 and returned Vogtle Unit 3 to the NRC's baseline inspection program.

Various design and other licensing-based compliance matters, including the timely submittal by Southern Nuclear of the ITAAC documentation for each unit and the related reviews and approvals by the NRC necessary to support NRC authorization to load fuel, have arisen or may arise, which may result in additional license amendments or require other resolution. If any license amendment requests or other licensing-based compliance issues, including inspections and ITAACs, are not resolved in a timely manner, there may be delays in the project schedule that could result in increased costs.

The ultimate outcome of these matters cannot be determined at this time. However, any extension of the in-service date beyond the first quarter 2023 for Unit 3 or the fourth quarter 2023 for Unit 4, including the current level of cost sharing described below, is estimated to result in additional base capital costs for Georgia Power of up to $60 million per month for Unit 3 and $40 million per month for Unit 4, as well as the related AFUDC and any additional related construction, support resources, or testing costs. While Georgia Power is not precluded from seeking retail recovery of any future capital cost forecast increase other than the amounts related to the cost-sharing and tender provisions of the joint ownership agreements described below, management will ultimately determine whether or not to seek recovery. Any further changes to the capital cost forecast that are not expected to be recoverable through regulated rates will be required to be charged to income and such charges could be material.

Joint Owner Contracts

In November 2017, the Vogtle Owners entered into an amendment to their joint ownership agreements for Plant Vogtle Units 3 and 4 to provide for, among other conditions, additional Vogtle Owner approval requirements. Effective in August 2018, the Vogtle Owners further amended the joint ownership agreements to clarify and provide procedures for certain provisions of the joint ownership agreements related to adverse events that require the vote of the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 to continue construction (as amended, and together with the November 2017 amendment, the Vogtle Joint Ownership Agreements). The Vogtle Joint Ownership Agreements also confirm that the Vogtle Owners' sole recourse against Georgia Power or Southern

Nuclear for any action or inaction in connection with their performance as agent for the Vogtle Owners is limited to removal of Georgia Power and/or Southern Nuclear as agent, except in cases of willful misconduct.

Amendments to the Vogtle Joint Ownership Agreements

In connection with a September 2018 vote by the Vogtle Owners to continue construction, Georgia Power entered into (i) a binding term sheet (Vogtle Owner Term Sheet) with the other Vogtle Owners and MEAG Power's wholly-owned subsidiaries MEAG Power SPVJ, LLC (MEAG SPVJ), MEAG Power SPVM, LLC (MEAG SPVM), and MEAG Power SPVP, LLC (MEAG SPVP) to take certain actions which partially mitigate potential financial exposure for the other Vogtle Owners, including additional amendments to the Vogtle Joint Ownership Agreements and the purchase of PTCs from the other Vogtle Owners at pre-established prices, and (ii) a term sheet (MEAG Term Sheet) with MEAG Power and MEAG SPVJ to provide up to $300 million of funding with respect to MEAG SPVJ's ownership interest in Plant Vogtle Units 3 and 4 under certain circumstances. In January 2019, Georgia Power, MEAG Power, and MEAG SPVJ entered into an agreement to implement the provisions of the MEAG Term Sheet. In February 2019, Georgia Power, the other Vogtle Owners, and MEAG Power's wholly-owned subsidiaries MEAG SPVJ, MEAG SPVM, and MEAG SPVP entered into certain amendments to the Vogtle Joint Ownership Agreements to implement the provisions of the Vogtle Owner Term Sheet (Global Amendments).

Pursuant to the Global Amendments: (i) each Vogtle Owner must pay its proportionate share of qualifying construction costs for Plant Vogtle Units 3 and 4 based on its ownership percentage up to the estimated cost at completion (EAC) for Plant Vogtle Units 3 and 4 which formed the basis of Georgia Power's forecast of $8.4 billion in the nineteenth VCM plus $800 million; (ii) Georgia Power will be responsible for 55.7% of actual qualifying construction costs between $800 million and $1.6 billion over the EAC in the nineteenth VCM (resulting in $80 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 44.3% of such costs pro rata in accordance with their respective ownership interests; and (iii) Georgia Power will be responsible for 65.7% of qualifying construction costs between $1.6 billion and $2.1 billion over the EAC in the nineteenth VCM (resulting in a further $100 million of potential additional costs to Georgia Power), with the remaining Vogtle Owners responsible for 34.3% of such costs pro rata in accordance with their respective ownership interests. If the EAC is revised and exceeds the EAC in the nineteenth VCM by more than $2.1 billion, each of the other Vogtle Owners will have a one-time option at the time the project budget cost forecast is so revised to tender a portion of its ownership interest to Georgia Power in exchange for Georgia Power's agreement to pay 100% of such Vogtle Owner's remaining share of total construction costs in excess of the EAC in the nineteenth VCM plus $2.1 billion.

For purposes of the foregoing provisions, qualifying construction costs will not include costs (i) resulting from force majeure events, including epidemics and quarantines, governmental actions or inactions (or significant delays associated with issuance of such actions) that affect the licensing, completion, start-up, operations, or financing of Plant Vogtle Units 3 and 4, administrative proceedings or litigation regarding ITAAC or other regulatory challenges to commencement of operation of Plant Vogtle Units 3 and 4, and changes in laws or regulations governing Plant Vogtle Units 3 and 4, (ii) legal fees and legal expenses incurred due to litigation with contractors or subcontractors that are not subsidiaries or affiliates of Southern Company, and (iii) additional costs caused by requests from the Vogtle Owners other than Georgia Power, except for the exercise of a right to vote granted under the Vogtle Joint Ownership Agreements, that increase costs by $100,000 or more.

In addition, pursuant to the Global Amendments, the holders of at least 90% of the ownership interests in Plant Vogtle Units 3 and 4 must vote to continue construction if certain adverse events occur, including, among other events: (i) the bankruptcy of Toshiba; (ii) the termination or rejection in bankruptcy of certain agreements, including the Vogtle Services Agreement, the Bechtel Agreement, or the agency agreement with Southern Nuclear; (iii) Georgia Power's public announcement of its intention not to submit for rate recovery any portion of its investment in Plant Vogtle Units 3 and 4 or the Georgia PSC determines that any of Georgia Power's costs relating to the construction of Plant Vogtle Units 3 and 4 will not be recovered in retail rates, excluding any additional amounts paid by Georgia Power on behalf of the other Vogtle Owners pursuant to the Global Amendments described above and the first 6% of costs during any six-month VCM reporting period that are disallowed by the Georgia PSC for

recovery, or for which Georgia Power elects not to seek cost recovery, through retail rates; and (iv) an incremental extension of one year or more from the seventeenth VCM report estimated in-service dates of November 2021 and November 2022 for Units 3 and 4, respectively. The schedule extension announced in February 2022 triggered the requirement for a vote to continue construction. Effective February 25, 2022, all of the Vogtle Owners had voted to continue construction.

Georgia Power and the other Vogtle Owners do not agree on either the starting dollar amount for the determination of cost increases subject to the cost-sharing and tender provisions of the Global Amendments or the extent to which COVID-19-related costs impact those provisions. Based on the definition in the Global Amendments, Georgia Power believes the starting dollar amount is $18.38 billion and the current project capital cost forecast exceeds the cost-sharing provision threshold, but not the tender provision threshold. The other Vogtle Owners have notified Georgia Power that they believe the current project capital cost forecast exceeds the cost-sharing thresholds and triggers the tender provisions under the Global Amendments. Georgia Power recorded a pre-tax charge to income in the fourth quarter 2021 of approximately $440 million ($328 million after tax) associated with these cost-sharing and tender provisions, which is included in the total project capital cost forecast. Georgia Power may be required to record further pre-tax charges to income of up to approximately $460 million associated with these provisions based on the current project capital cost forecast. Georgia Power's incremental charges associated with these provisions, which relate to the other Vogtle Owners' share of costs, will not be recovered from retail customers. In October 2021, Georgia Power and the other Vogtle Owners entered into an agreement to clarify the process for the tender provisions of the Global Amendments to provide for a decision between 120 and 180 days after the tender option is triggered, which the other Vogtle Owners assert occurred on February 14, 2022.

Georgia Power's ownership interest in Plant Vogtle Units 3 and 4 continues to be 45.7%; however, it could increase if one or more of the other Vogtle Owners exercise the option to tender a portion of their ownership interest to Georgia Power and require Georgia Power to pay 100% of the remaining share of the costs necessary to complete Plant Vogtle Units 3 and 4. Georgia Power's incremental ownership interest would be calculated and conveyed to Georgia Power after Plant Vogtle Units 3 and 4 are placed in service.

The ultimate outcome of these matters cannot be determined at this time.

Regulatory Matters

In 2009, the Georgia PSC voted to certify construction of Plant Vogtle Units 3 and 4 with a certified capital cost of $4.418 billion. In addition, in 2009 the Georgia PSC approved inclusion of the Plant Vogtle Units 3 and 4 related CWIP accounts in rate base, and the State of Georgia enacted the Georgia Nuclear Energy Financing Act, which allows Georgia Power to recover financing costs for Plant Vogtle Units 3 and 4. Financing costs are recovered on all applicable certified costs through annual adjustments to the NCCR tariff up to the certified capital cost of $4.418 billion. At March 31, 2022, Georgia Power had recovered approximately $2.8 billion of financing costs. Financing costs related to capital costs above $4.418 billion are being recognized through AFUDC and are expected to be recovered through retail rates over the life of Plant Vogtle Units 3 and 4; however, Georgia Power is not recording AFUDC related to any capital costs in excess of the total deemed reasonable by the Georgia PSC (currently $7.3 billion) and not requested for rate recovery. In November 2021, the Georgia PSC approved Georgia Power's request to decrease the NCCR tariff by $78 million annually, effective January 1, 2022.

Georgia Power is required to file semi-annual VCM reports with the Georgia PSC by February 28 and August 31 of each year. In 2013, in connection with the eighth VCM report, the Georgia PSC approved a stipulation between Georgia Power and the staff of the Georgia PSC to waive the requirement to amend the Plant Vogtle Units 3 and 4 certificate in accordance with the 2009 certification order until the completion of Plant Vogtle Unit 3, or earlier if deemed appropriate by the Georgia PSC and Georgia Power.

In 2016, the Georgia PSC voted to approve a settlement agreement (Vogtle Cost Settlement Agreement) resolving certain prudency matters in connection with the fifteenth VCM report. In December 2017, the Georgia PSC voted to approve (and issued its related order on January 11, 2018) Georgia Power's seventeenth VCM report and modified the Vogtle Cost Settlement Agreement. The Vogtle Cost Settlement Agreement, as modified by the January 11,

2018 order, resolved the following regulatory matters related to Plant Vogtle Units 3 and 4: (i) none of the $3.3 billion of costs incurred through December 31, 2015 and reflected in the fourteenth VCM report should be disallowed from rate base on the basis of imprudence; (ii) the Contractor Settlement Agreement was reasonable and prudent and none of the $0.3 billion paid pursuant to the Contractor Settlement Agreement should be disallowed from rate base on the basis of imprudence; (iii) (a) capital costs incurred up to $5.68 billion would be presumed to be reasonable and prudent with the burden of proof on any party challenging such costs, (b) Georgia Power would have the burden to show that any capital costs above $5.68 billion were prudent, and (c) a revised capital cost forecast of $7.3 billion (after reflecting the impact of payments received under the Guarantee Settlement Agreement and related customer refunds) was found reasonable; (iv) construction of Plant Vogtle Units 3 and 4 should be completed, with Southern Nuclear serving as project manager and Bechtel as primary contractor; (v) approved and deemed reasonable Georgia Power's revised schedule placing Plant Vogtle Units 3 and 4 in service in November 2021 and November 2022, respectively; (vi) confirmed that the revised cost forecast does not represent a cost cap and that a prudence proceeding on cost recovery will occur following Unit 4 fuel load, consistent with applicable Georgia law; (vii) reduced the ROE used to calculate the NCCR tariff (a) from 10.95% (the ROE rate setting point authorized by the Georgia PSC in the 2013 alternate rate plan) to 10.00% effective January 1, 2016, (b) from 10.00% to 8.30%, effective January 1, 2020, and (c) from 8.30% to 5.30%, effective January 1, 2021 (provided that the ROE in no case will be less than Georgia Power's average cost of long-term debt); (viii) reduced the ROE used for AFUDC equity for Plant Vogtle Units 3 and 4 from 10.00% to Georgia Power's average cost of long-term debt, effective January 1, 2018; and (ix) agreed that effective the first month after Unit 3 reaches commercial operation, retail base rates would be adjusted to include the costs related to Unit 3 and common facilities deemed prudent in the Vogtle Cost Settlement Agreement (see Note 2 to the financial statements under "Georgia Power – Plant Vogtle Unit 3 and Common Facilities Rate Proceeding" in Item 8 of the Form 10-K for additional information). The January 11, 2018 order also stated that if Plant Vogtle Units 3 and 4 are not commercially operational by June 1, 2021 and June 1, 2022, respectively, the ROE used to calculate the NCCR tariff will be further reduced by 10 basis points each month (but not lower than Georgia Power's average cost of long-term debt) until the respective Unit is commercially operational. The ROE reductions negatively impacted earnings by approximately $270 million in 2021 and are estimated to have negative earnings impacts of approximately $300 million and $265 million in 2022 and 2023, respectively. In its January 11, 2018 order, the Georgia PSC also stated if other conditions change and assumptions upon which Georgia Power's seventeenth VCM report are based do not materialize, the Georgia PSC reserved the right to reconsider the decision to continue construction.

In the August 2021 order approving the twenty-fourth VCM report, the Georgia PSC approved a stipulation addressing the following matters: (i) beginning with its twenty-fifth VCM report, Georgia Power will continue to report to the Georgia PSC all costs incurred during the period for review and will request for approval costs up to the $7.3 billion determined to be reasonable in the Georgia PSC's seventeenth VCM order and (ii) Georgia Power will not seek rate recovery of the $0.7 billion increase to the base capital cost forecast included in the nineteenth VCM report and charged to income by Georgia Power in the second quarter 2018. In addition, the stipulation confirms Georgia Power may request verification and approval of costs above $7.3 billion for inclusion in rate base at a later time, but no earlier than the prudence review contemplated by the seventeenth VCM order described previously.

The Georgia PSC has approved 25 VCM reports covering periods through June 30, 2021. These reports reflect total construction capital costs incurred of $7.9 billion (net of $1.7 billion of payments received under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds), of which the Georgia PSC has verified and approved $7.3 billion as described above. Georgia Power filed its twenty-sixth VCM report with the Georgia PSC on February 17, 2022, reflecting $584 million of additional construction capital costs incurred through December 31, 2021 and the total capital cost forecast described above.

The ultimate outcome of these matters cannot be determined at this time.

Mississippi Power

Performance Evaluation Plan

On March 15, 2022, Mississippi Power submitted its annual retail PEP filing for 2022 to the Mississippi PSC, which requested a 1.9%, or approximately $18 million, annual increase in revenues, primarily due to increases in investment, operations and maintenance expenses, and depreciation and amortization. In accordance with the PEP rate schedule, the rate increase became effective with the first billing cycle of April 2022, subject to refund. The related proceedings are expected to conclude in summer 2022; however, the ultimate outcome of this matter cannot be determined at this time.

Ad Valorem Tax Adjustment

On April 13, 2022, Mississippi Power submitted its annual ad valorem tax adjustment filing for 2022, which requested a $5 million annual increase in revenues. The ultimate outcome of this matter cannot be determined at this time.

Southern Company Gas

Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2022 were as follows:

Utility	Program	Three Months Ended March 31, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	51
Virginia Natural Gas	Steps to Advance Virginia's Energy	14
Atlanta Gas Light	System Reinforcement Rider	14
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	80

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Contingencies

3 Months Ended

Mar. 31, 2022

Commitments and Contingencies Disclosure [Abstract]

Contingencies

CONTINGENCIESSee Note 3 to the financial statements in Item 8 of the Form 10-K for information relating to various lawsuits and other contingencies.

General Litigation Matters

The Registrants are involved in various matters being litigated and regulatory matters. The ultimate outcome of such pending or potential litigation or regulatory matters against each Registrant and any subsidiaries cannot be determined at this time; however, for current proceedings not specifically reported herein, management does not anticipate that the ultimate liabilities, if any, arising from such current proceedings would have a material effect on such Registrant's financial statements.

The Registrants believe the pending legal challenges discussed below have no merit; however, the ultimate outcome of these matters cannot be determined at this time.

Southern Company

In February 2017, Jean Vineyard and Judy Mesirov each filed a shareholder derivative lawsuit in the U.S. District Court for the Northern District of Georgia. Each of these lawsuits names as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. In 2017, these two shareholder derivative lawsuits were consolidated in the U.S. District Court for the Northern District of

Georgia. The complaints allege that the defendants caused Southern Company to make false or misleading statements regarding the Kemper County energy facility cost and schedule. Further, the complaints allege that the defendants were unjustly enriched and caused the waste of corporate assets and also allege that the individual defendants violated their fiduciary duties.

In May 2017, Helen E. Piper Survivor's Trust filed a shareholder derivative lawsuit in the Superior Court of Gwinnett County, Georgia that names as defendants Southern Company, certain of its directors, certain of its current and former officers, and certain former Mississippi Power officers. The complaint alleges that the individual defendants, among other things, breached their fiduciary duties in connection with schedule delays and cost overruns associated with the construction of the Kemper County energy facility. The complaint further alleges that the individual defendants authorized or failed to correct false and misleading statements regarding the Kemper County energy facility schedule and cost and failed to implement necessary internal controls to prevent harm to Southern Company. In August 2019, the court granted a motion filed by the plaintiff in July 2019 to substitute a new named plaintiff, Martin J. Kobuck, in place of Helen E. Piper Survivor's Trust.

The plaintiffs in each of these cases seek to recover, on behalf of Southern Company, unspecified actual damages and, on each plaintiff's own behalf, attorneys' fees and costs in bringing the lawsuit. The plaintiffs also seek certain changes to Southern Company's corporate governance and internal processes. On January 21, 2022, the plaintiffs in the federal court action filed a motion for preliminary approval of settlement, together with an executed stipulation of settlement, which applies to both actions. On March 11, 2022, the U.S. District Court for the Northern District of Georgia entered an order preliminarily approving the settlement. The proposed settlement consists of an aggregate payment by Southern Company's insurers of approximately $4.5 million for attorneys' fees and expenses, as well as adoption of various corporate governance reforms by Southern Company. The terms of the proposed settlement and the corporate governance reforms remain subject to final approval by the court.

Georgia Power

In 2011, plaintiffs filed a putative class action against Georgia Power in the Superior Court of Fulton County, Georgia alleging that Georgia Power's collection in rates of amounts for municipal franchise fees (which fees are paid to municipalities) exceeded the amounts allowed in orders of the Georgia PSC and alleging certain state law claims. This case has been ruled upon and appealed numerous times over the last several years. In 2019, the Georgia PSC issued an order that found Georgia Power has appropriately implemented the municipal franchise fee schedule. In March 2021, the Superior Court of Fulton County granted class certification and Georgia Power's motion for summary judgment and the plaintiffs filed a notice of appeal. In April 2021, Georgia Power filed a notice of cross appeal on the issue of class certification. In December 2021, the Georgia Court of Appeals affirmed the Superior Court's ruling that granted summary judgment to Georgia Power and dismissed Georgia Power's cross appeal on the issue of class certification as moot. Also in December 2021, the plaintiffs filed a petition for writ of certiorari to the Georgia Supreme Court. The amount of any possible losses cannot be estimated at this time because, among other factors, it is unknown whether any losses would be subject to recovery from any municipalities.

In July 2020, a group of individual plaintiffs filed a complaint in the Superior Court of Fulton County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater, surface water, and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages, a medical monitoring fund, and injunctive relief. Georgia Power has filed multiple motions to dismiss the complaint. In October 2021, three additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power alleging that releases from Plant Scherer have impacted groundwater and air, resulting in alleged personal injuries and property damage. The plaintiffs seek an unspecified amount of monetary damages including punitive damages. In November 2021, Georgia Power filed a notice to remove the three cases pending in the Superior Court of Monroe County, Georgia to the U.S. District Court for the Middle District of Georgia. On February 7, 2022, four additional complaints were filed in the Superior Court of Monroe County, Georgia against Georgia Power seeking damages for alleged personal injuries or property damage. On March 9, 2022, Georgia Power filed a notice to remove the four cases pending in the Superior Court of Monroe

County, Georgia to the U.S. District Court for the Middle District of Georgia. The amount of any possible losses from these matters cannot be estimated at this time.

Mississippi Power

In 2018, Ray C. Turnage and 10 other individual plaintiffs filed a putative class action complaint against Mississippi Power and the three then-serving members of the Mississippi PSC in the U.S. District Court for the Southern District of Mississippi, which was amended in March 2019 to include four additional plaintiffs. Mississippi Power received Mississippi PSC approval in 2013 to charge a mirror CWIP rate premised upon including in its rate base pre-construction and construction costs for the Kemper IGCC prior to placing the Kemper IGCC into service. The Mississippi Supreme Court reversed that approval and ordered Mississippi Power to refund the amounts paid by customers under the previously-approved mirror CWIP rate. The plaintiffs allege that the initial approval process, and the amount approved, were improper and make claims for gross negligence, reckless conduct, and intentional wrongdoing. They also allege that Mississippi Power underpaid customers by up to $23.5 million in the refund process by applying an incorrect interest rate. The plaintiffs seek to recover, on behalf of themselves and their putative class, actual damages, punitive damages, pre-judgment interest, post-judgment interest, attorney's fees, and costs. The district court dismissed the amended complaint; however, in March 2020, the plaintiffs filed a motion seeking to name the new members of the Mississippi PSC, the Mississippi Development Authority, and Southern Company as additional defendants and add a cause of action against all defendants based on a dormant commerce clause theory under the U.S. Constitution. In July 2020, the plaintiffs filed a motion for leave to file a third amended complaint, which included the same federal claims as the proposed second amended complaint, as well as several additional state law claims based on the allegation that Mississippi Power failed to disclose the annual percentage rate of interest applicable to refunds. In November 2020, the district court denied each of the plaintiffs' pending motions and entered final judgment in favor of Mississippi Power. In January 2021, the district court denied further motions by the plaintiffs to vacate the judgment and to file a revised second amended complaint. In February 2021, the plaintiffs filed a notice of appeal with the U.S. Court of Appeals for the Fifth Circuit. On March 21, 2022, the U.S. Court of Appeals for the Fifth Circuit issued an opinion affirming the dismissal of the claims against the Mississippi PSC defendants but reversing the dismissal of the claims against Mississippi Power. The appellate court remanded the case to the U.S. District Court for the Southern District of Mississippi for further proceedings. The appellate court's decision is not final until the opportunity for rehearing en banc is resolved. An adverse outcome in this proceeding could have a material impact on Mississippi Power's financial statements.

Environmental Remediation

The Southern Company system must comply with environmental laws and regulations governing the handling and disposal of waste and releases of hazardous substances. Under these various laws and regulations, the Southern Company system could incur substantial costs to clean up affected sites. The traditional electric operating companies and the natural gas distribution utilities in Illinois and Georgia have each received authority from their respective state PSCs or other applicable state regulatory agencies to recover approved environmental remediation costs through regulatory mechanisms. These regulatory mechanisms are adjusted annually or as necessary within limits approved by the state PSCs or other applicable state regulatory agencies.

Georgia Power's environmental remediation liability was $16 million and $17 million at March 31, 2022 and December 31, 2021, respectively. Georgia Power has been designated or identified as a potentially responsible party at sites governed by the Georgia Hazardous Site Response Act and/or by the federal Comprehensive Environmental Response, Compensation, and Liability Act, and assessment and potential cleanup of such sites is expected.

Southern Company Gas' environmental remediation liability was $249 million at both March 31, 2022 and December 31, 2021 based on the estimated cost of environmental investigation and remediation associated with known former manufactured gas plant operating sites.

The ultimate outcome of these matters cannot be determined at this time; however, as a result of the regulatory treatment for environmental remediation expenses described above, the final disposition of these matters is not expected to have a material impact on the financial statements of the applicable Registrants.

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Revenue from Contracts with Customers and Lease Income

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers and Lease Income

REVENUE FROM CONTRACTS WITH CUSTOMERS AND LEASE INCOME

Revenue from Contracts with Customers

The Registrants generate revenues from a variety of sources, some of which are not accounted for as revenue from contracts with customers, such as leases, derivatives, and certain cost recovery mechanisms. See Note 1 to the financial statements under "Revenues" in Item 8 of the Form 10-K for additional information on the revenue policies of the Registrants. See "Lease Income" herein and Note (J) for additional information on revenue accounted for under lease and derivative accounting guidance, respectively.

The following table disaggregates revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(a)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Operating revenues
Retail electric revenues
Residential	$	1,468	$	628	$	776	$	64	$	—	$	—
Commercial	1,117		372		686		59		—		—
Industrial	668		320		284		64		—		—
Other	24		5		17		2		—		—
Total retail electric revenues	3,277		1,325		1,763		189		—		—
Natural gas distribution revenues
Residential	614		—		—		—		—		614
Commercial	170		—		—		—		—		170
Transportation	288		—		—		—		—		288
Industrial	16		—		—		—		—		16
Other	97		—		—		—		—		97
Total natural gas distribution revenues	1,185		—		—		—		—		1,185
Wholesale electric revenues
PPA energy revenues	212		43		13		4		156		—
PPA capacity revenues	119		29		13		3		75		—
Non-PPA revenues	67		32		9		88		61		—
Total wholesale electric revenues	398		104		35		95		292		—
Other natural gas revenues
Wholesale gas services	1,590		—		—		—		—		1,590
Gas marketing services	194		—		—		—		—		194
Other natural gas revenues	7		—		—		—		—		7
Total natural gas revenues	1,791		—		—		—		—		1,791
Other revenues	249		46		113		8		4		—
Total revenue from contracts with customers	6,900		1,475		1,911		292		296		2,976
Other revenue sources(a)	1,306		84		59		15		144		1,014
Other adjustments(b)	(2,296)		—		—		—		—		(2,296)
Total operating revenues	$	5,910	$	1,559	$	1,970	$	307	$	440	$	1,694

(a)Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas, and cost recovery mechanisms and revenues that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at March 31, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2022	$	2,571	$	616	$	695	$	85	$	128	$	865
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At March 31, 2022	$	81	$	2	$	31	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At March 31, 2022	$	72	$	3	$	13	$	2	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

At March 31, 2022 and December 31, 2021, Georgia Power had contract assets primarily related to retail customer fixed bill programs, where the payment is contingent upon Georgia Power's continued performance and the customer's continued participation in the program over a one-year contract term, and unregulated service agreements, where payment is contingent on project completion. Contract liabilities for Georgia Power relate to cash collections recognized in advance of revenue for unregulated service agreements. Southern Company's unregulated distributed generation business had $47 million and $50 million of contract assets and $54 million and $39 million of contract liabilities at March 31, 2022 and December 31, 2021, respectively, for outstanding performance obligations.

Revenues recognized in the three months ended March 31, 2022, which were included in contract liabilities at December 31, 2021, were immaterial for all Registrants.

Remaining Performance Obligations

The Subsidiary Registrants have long-term contracts with customers in which revenues are recognized as performance obligations are satisfied over the contract term. For the traditional electric operating companies and Southern Power, these contracts primarily relate to PPAs whereby electricity and generation capacity are provided to a customer. The revenue recognized for the delivery of electricity is variable; however, certain PPAs include a fixed payment for fixed generation capacity over the term of the contract. Southern Company's unregulated distributed generation business also has partially satisfied performance obligations related to certain fixed price contracts. Revenues from contracts with customers related to these performance obligations remaining at March 31, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	529	$	459	$	351	$	321	$	307	$	2,345
Alabama Power	24		24		7		5		—		—
Georgia Power	55		55		26		22		11		21
Southern Power	252		294		310		294		299		2,339

Revenue expected to be recognized for performance obligations remaining at March 31, 2022 was immaterial for Mississippi Power and Southern Company Gas.

Lease Income

Lease income for the three months ended March 31, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9
For the Three Months Ended March 31, 2021
Lease income - interest income on sales-type leases	$	3	$	—	$	—	$	3	$	—	$	—
Lease income - operating leases	55		21		10		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	142	$	21	$	10	$	3	$	111	$	9

Lease payments received under tolling arrangements and PPAs consist of either scheduled payments or variable payments based on the amount of energy produced by the underlying electric generating units. Lease income for Alabama Power and Southern Power is included in wholesale revenues.

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Consolidated Entities and Equity Method Investments

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Consolidated Entities and Equity Method Investments

CONSOLIDATED ENTITIES AND EQUITY METHOD INVESTMENTSSee Note 7 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Power

Variable Interest Entities

Southern Power has certain subsidiaries that are determined to be VIEs. Southern Power is considered the primary beneficiary of these VIEs because it controls the most significant activities of the VIEs, including operating and maintaining the respective assets, and has the obligation to absorb expected losses of these VIEs to the extent of its equity interests.

SP Solar and SP Wind

At March 31, 2022 and December 31, 2021, SP Solar had total assets of $6.0 billion and $6.1 billion, respectively, total liabilities of $407 million and $408 million, respectively, and noncontrolling interests of $1.1 billion. Cash distributions from SP Solar are allocated 67% to Southern Power and 33% to Global Atlantic in accordance with their partnership interest percentage. Under the terms of the limited partnership agreement, distributions without limited partner consent are limited to available cash and SP Solar is obligated to distribute all such available cash to its partners each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves.

At March 31, 2022 and December 31, 2021, SP Wind had total assets of $2.3 billion, total liabilities of $180 million and $130 million, respectively, and noncontrolling interests of $41 million. Under the terms of the limited liability agreement, distributions without Class A member consent are limited to available cash and SP Wind is obligated to distribute all such available cash to its members each quarter. Available cash includes all cash generated in the quarter subject to the maintenance of appropriate operating reserves. Cash distributions from SP Wind are generally allocated 60% to Southern Power and 40% to the three financial investors in accordance with the limited liability agreement.

Southern Power consolidates both SP Solar and SP Wind, as the primary beneficiary, since it controls the most significant activities of each entity, including operating and maintaining their assets. Certain transfers and sales of the assets in the VIEs are subject to partner consent and the liabilities are non-recourse to the general credit of Southern Power. Liabilities consist of customary working capital items and do not include any long-term debt.

Other Variable Interest Entities

Southern Power has other consolidated VIEs that relate to certain subsidiaries that have either sold noncontrolling interests to tax equity investors or acquired less than a 100% interest from facility developers. These entities are considered VIEs because the arrangements are structured similar to a limited partnership and the noncontrolling members do not have substantive kick-out rights.

At March 31, 2022 and December 31, 2021, the other VIEs had total assets of $1.8 billion and $1.9 billion, respectively, total liabilities of $248 million and $263 million, respectively, and noncontrolling interests of $876 million and $886 million, respectively. Under the terms of the partnership agreements, distributions of all available cash are required each month or quarter and additional distributions require partner consent.

Equity Method Investments

At March 31, 2022 and December 31, 2021, Southern Power had equity method investments in wind and battery energy storage projects totaling $56 million and $86 million, respectively. Earnings (loss) from these investments were immaterial for both periods presented. During the first quarter 2022, Southern Power sold an equity method investment in a wind project and received proceeds of $31 million. The gain associated with the transaction was immaterial.

Southern Company Gas

Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2022 and December 31, 2021 and related earnings from those investments for the three months ended March 31, 2022 and 2021 were as follows:

Investment Balance	March 31, 2022		December 31, 2021
	(in millions)
SNG	$	1,138	$	1,129
Other(*)	40		44
Total	$	1,178	$	1,173

(*)Balance at March 31, 2022 reflects a $4 million distribution from PennEast Pipeline.

	Three Months Ended March 31,
Earnings from Equity Method Investments	2022		2021
	(in millions)
SNG	$	39	$	38
Other(*)	1		3
Total	$	40	$	41

(*)Earnings primarily result from AFUDC equity recorded by the project entity.

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Financing

3 Months Ended

Mar. 31, 2022

Debt Disclosure [Abstract]

Financing

FINANCING

Bank Credit Arrangements

See Note 8 to the financial statements under "Bank Credit Arrangements" in Item 8 of the Form 10-K for additional information.

At March 31, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2022		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		255		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,747		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,574	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $19 million, respectively, was unused at March 31, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of the arrangement expiring in 2026 and all $250 million of the arrangement expiring in 2022. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

As reflected in the table above, in March 2022, Mississippi Power amended and restated its $125 million revolving credit arrangement, which among other things, extended the maturity date from 2023 to 2025 and allows for borrowing based on term SOFR.

Subject to applicable market conditions, Southern Company and its subsidiaries expect to renew or replace their bank credit arrangements as needed, prior to expiration. In connection therewith, Southern Company and its subsidiaries may extend the maturity dates and/or increase or decrease the lending commitments thereunder.

These bank credit arrangements, as well as the term loan arrangements of the Registrants, Nicor Gas, and SEGCO, contain covenants that limit debt levels and contain cross-acceleration or, in the case of Southern Power, cross-default provisions to other indebtedness (including guarantee obligations) that are restricted only to the indebtedness of the individual company. Such cross-default provisions to other indebtedness would trigger an event of default if Southern Power defaulted on indebtedness or guarantee obligations over a specified threshold. Such cross-acceleration provisions to other indebtedness would trigger an event of default if the applicable borrower defaulted on indebtedness, the payment of which was then accelerated. At March 31, 2022, the Registrants, Nicor Gas, and SEGCO were in compliance with all such covenants. None of the bank credit arrangements contain material adverse change clauses at the time of borrowings.

A portion of the unused credit with banks is allocated to provide liquidity support to the revenue bonds of the traditional electric operating companies and the commercial paper programs of the Registrants, Nicor Gas, and SEGCO. The amount of variable rate revenue bonds of the traditional electric operating companies outstanding requiring liquidity support at March 31, 2022 was approximately $1.5 billion (comprised of approximately $789 million at Alabama Power, $672 million at Georgia Power, and $34 million at Mississippi Power). In addition, at March 31, 2022, Georgia Power had approximately $330 million of fixed rate revenue bonds outstanding that are required to be remarketed within the next 12 months.

Earnings per Share

For Southern Company, the only differences in computing basic and diluted earnings per share are attributable to awards outstanding under stock-based compensation plans and the equity units issued in 2019. Earnings per share dilution resulting from stock-based compensation plans and the equity units issuance is determined using the treasury stock method. See Note 8 to the financial statements under "Equity Units" in Item 8 of the Form 10-K for information on the equity units and Note 12 to the financial statements in Item 8 of the Form 10-K for information on stock-based compensation plans. Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31,
	2022	2021
	(in millions)
As reported shares	1,063	1,060
Effect of stock-based compensation	6	6
Diluted shares	1,069	1,066

An immaterial number of stock-based compensation awards was not included in the diluted earnings per share calculation because the awards were anti-dilutive for the three months ended March 31, 2022 and 2021.

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Income Taxes

3 Months Ended

Mar. 31, 2022

Income Tax Disclosure [Abstract]

Income Taxes

INCOME TAXES

See Note 10 to the financial statements in Item 8 of the Form 10-K for additional tax information.

Current and Deferred Income Taxes

Tax Credit and Net Operating Loss Carryforwards

The utilization of each Registrant's estimated tax credit and state net operating loss carryforwards and related valuation allowances could be impacted by numerous factors, including the acquisition of additional renewable projects, an increase in Georgia Power's ownership interest percentage in Plant Vogtle Units 3 and 4, the purchase of rights to additional PTCs of Plant Vogtle Units 3 and 4 pursuant to certain joint ownership agreements, changes in taxable income projections, and potential income tax rate changes. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information on Plant Vogtle Units 3 and 4.

Effective Tax Rate

Southern Company's effective tax rate is typically lower than the statutory rate due to employee stock plans' dividend deduction, non-taxable AFUDC equity at the traditional electric operating companies, flowback of excess deferred income taxes at the regulated utilities, and federal income tax benefits from ITCs and PTCs primarily at Southern Power.

Details of significant changes in the effective tax rate for the applicable Registrants are provided herein.

Mississippi Power

Mississippi Power's effective tax rate was 16.4% for the three months ended March 31, 2022 compared to 8.4% for the corresponding period in 2021. The effective tax rate increase was primarily due to a decrease in the flowback of excess deferred income taxes beginning in April 2021.

Southern Power

Southern Power's effective tax benefit rate was (80.0)% for the three months ended March 31, 2022 compared to (17.3)% for the corresponding period in 2021. The effective tax rate decrease was primarily due to lower pre-tax earnings and higher wind PTCs in 2022, partially offset by changes in state apportionment methodology resulting from tax legislation enacted by the State of Alabama in February 2021.

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Retirement Benefits

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Retirement Benefits

RETIREMENT BENEFITS

The Southern Company system has a qualified defined benefit, trusteed, pension plan covering substantially all employees, with the exception of employees at PowerSecure. The qualified pension plan is funded in accordance with requirements of the Employee Retirement Income Security Act of 1974, as amended (ERISA). No mandatory contributions to the qualified pension plan are anticipated for the year ending December 31, 2022. The Southern Company system also provides certain non-qualified defined benefits for a select group of management and highly compensated employees, which are funded on a cash basis. In addition, the Southern Company system provides certain medical care and life insurance benefits for retired employees through other postretirement benefit plans. The traditional electric operating companies fund other postretirement trusts to the extent required by their respective regulatory commissions. Southern Company Gas has a separate unfunded supplemental retirement health care plan that provides medical care and life insurance benefits to employees of discontinued businesses.

During the first quarter 2022, the qualified pension plan achieved the predetermined funding threshold whereby the asset allocation was adjusted to invest a larger portion of the portfolio in fixed rate debt securities.

See Note 11 to the financial statements in Item 8 of the Form 10-K for additional information.

On each Registrant's condensed statements of income, the service cost component of net periodic benefit costs is included in other operations and maintenance expenses and all other components of net periodic benefit costs are included in other income (expense), net. Components of the net periodic benefit costs for the three months ended March 31, 2022 and 2021 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Pension Plans
Service cost	$	109	$	26	$	28	$	4	$	2	$	9
Interest cost	87		20		26		4		1		6
Expected return on plan assets	(298)		(72)		(94)		(14)		(3)		(21)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	78		21		25		4		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(15)	$	(2)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	8		2		3		—		—		1
Expected return on plan assets	(19)		(7)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net (gain)/loss	1		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	—

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Fair Value Measurements

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Fair Value Measurements

FAIR VALUE MEASUREMENTS

At March 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Southern Company
Assets:
Energy-related derivatives(a)	$	74	$	473	$	—	$	—	$	547
Interest rate derivatives	—		17		—		—		17
Investments in trusts:(b)(c)
Domestic equity	754		202		—		—		956
Foreign equity	143		167		—		—		310
U.S. Treasury and government agency securities	—		290		—		—		290
Municipal bonds	—		53		—		—		53
Pooled funds – fixed income	—		10		—		—		10
Corporate bonds	1		490		—		—		491
Mortgage and asset backed securities	—		88		—		—		88
Private equity	—		—		—		156		156
Cash and cash equivalents	3		—		—		—		3
Other	42		25		—		—		67
Cash equivalents	1,182		17		—		—		1,199
Other investments	9		32		—		—		41
Total	$	2,208	$	1,864	$	—	$	156	$	4,228
Liabilities:
Energy-related derivatives(a)	$	3	$	7	$	—	$	—	$	10
Interest rate derivatives	—		139		—		—		139
Foreign currency derivatives	—		130		—		—		130
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	3	$	289	$	14	$	—	$	306

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Alabama Power
Assets:
Energy-related derivatives	$	—	$	128	$	—	$	—	$	128
Nuclear decommissioning trusts:(b)
Domestic equity	452		193		—		—		645
Foreign equity	143		—		—		—		143
U.S. Treasury and government agency securities	—		21		—		—		21
Municipal bonds	—		2		—		—		2
Corporate bonds	1		253		—		—		254
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		156		156
Other	14		—		—		—		14
Cash equivalents	1,129		17		—		—		1,146
Other investments	—		32		—		—		32
Total	$	1,739	$	666	$	—	$	156	$	2,561
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Georgia Power
Assets:
Energy-related derivatives	$	—	$	179	$	—	$	—	$	179
Interest rate derivatives	—		12		—		—		12
Nuclear decommissioning trusts:(b)(c)
Domestic equity	302		1		—		—		303
Foreign equity	—		165		—		—		165
U.S. Treasury and government agency securities	—		269		—		—		269
Municipal bonds	—		51		—		—		51
Corporate bonds	—		237		—		—		237
Mortgage and asset backed securities	—		68		—		—		68
Other	28		25		—		—		53
Total	$	330	$	1,007	$	—	$	—	$	1,337
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Mississippi Power
Assets:
Energy-related derivatives	$	—	$	138	$	—	$	—	$	138
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Southern Power
Assets:
Energy-related derivatives	$	—	$	8	$	—	$	—	$	8
Liabilities:
Foreign currency derivatives	$	—	$	43	$	—	$	—	$	43
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	56	$	14	$	—	$	70
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	74	$	20	$	—	$	—	$	94
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		10		—		—		10
Cash equivalents	3		—		—		—		3
Total	$	77	$	40	$	—	$	—	$	117
Liabilities:
Energy-related derivatives(a)	$	3	$	1	$	—	$	—	$	4
Interest rate derivatives	—		36		—		—		36
Total	$	3	$	37	$	—	$	—	$	40

(a)Excludes cash collateral of $36 million.

(b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At March 31, 2022, approximately $72 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Company, Alabama Power, and Georgia Power continue to elect the option to fair value investment securities held in the nuclear decommissioning trust funds. The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for the three months ended March 31, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended March 31, 2022		Three Months Ended March 31, 2021
	(in millions)
Southern Company	$	(150)	$	39
Alabama Power	(67)		41
Georgia Power	(83)		(2)

Valuation Methodologies

The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used.

For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available.

The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information.

Southern Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate. The fair value of contingent consideration reflects the net present value of expected payments and any periodic change arising from forecasted generation is expected to be immaterial.

Southern Power also has payment obligations through 2040 whereby it must reimburse the transmission owners for interconnection facilities and network upgrades constructed to support connection of a Southern Power generating facility to the transmission system. The obligations are categorized as Level 2 under Fair Value Measurements as the fair value is determined using observable inputs for the contracted amounts and reimbursement period, as well as a discount rate. The fair value of the obligations reflects the net present value of expected payments.

"Other investments" include investments traded in the open market that have maturities greater than 90 days, which are categorized as Level 2 under Fair Value Measurements and are comprised of corporate bonds, bank certificates of deposit, treasury bonds, and/or agency bonds.

At March 31, 2022, the fair value measurements of private equity investments held in Alabama Power's nuclear decommissioning trusts that are calculated at net asset value per share (or its equivalent) as a practical expedient totaled $156 million and unfunded commitments related to the private equity investments totaled $84 million. Private equity investments include high-quality private equity funds across several market sectors and funds that invest in real estate assets. Private equity funds do not have redemption rights. Distributions from these funds will be received as the underlying investments in the funds are liquidated.

At March 31, 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas(*)
	(in billions)
Long-term debt, including securities due within one year:
Carrying amount	$	51.6	$	9.8	$	13.2	$	1.5	$	3.7	$	6.9
Fair value	51.9		10.0		13.5		1.5		3.8		6.9

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043.

The fair values are determined using Level 2 measurements and are based on quoted market prices for the same or similar issues or on the current rates available to the Registrants.

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Derivatives

3 Months Ended

Mar. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivatives

DERIVATIVESThe Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 to the financial statements under "Financial Instruments" in Item 8 of the Form 10-K for additional information. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

Energy-Related Derivatives

The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations.

Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in operating revenues.

Energy-related derivative contracts are accounted for under one of three methods:

•Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism.

•Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in accumulated OCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions.

•Not Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered.

At March 31, 2022, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows:

	Net Purchased mmBtu	Longest Hedge Date	Longest Non-Hedge Date
	(in millions)
Southern Company(*)	279	2030	2025
Alabama Power	65	2025	—
Georgia Power	75	2024	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	64	2024	2025

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 66.2 million mmBtu and short natural gas positions of 2.6 million mmBtu at March 31, 2022, which is also included in Southern Company's total volume.

In addition to the volumes discussed above, the traditional electric operating companies and Southern Power enter into physical natural gas supply contracts that provide the option to sell back excess natural gas due to operational constraints. The maximum expected volume of natural gas subject to such a feature is 18 million mmBtu for Southern Company, which includes 4 million mmBtu for Alabama Power, 6 million mmBtu for Georgia Power, 3 million mmBtu for Mississippi Power, and 5 million mmBtu for Southern Power.

For cash flow hedges of energy-related derivatives, the estimated pre-tax gains expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $29 million for Southern Company, $26 million for Southern Company Gas, and immaterial for all other Registrants.

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

At March 31, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	200	1.87%	—	February 2032	$	8
Georgia Power	100		2.27%	—	November 2051	4
Cash Flow Hedges of Existing Debt
Southern Company parent	100		2.58%	—	April 2027	(1)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(29)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(69)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(35)
Southern Company	$	2,300				$	(122)

For cash flow hedge interest rate derivatives, the estimated pre-tax gains (losses) expected to be reclassified from accumulated OCI to interest expense for the 12-month period ending March 31, 2023 total $(20) million for Southern Company and are immaterial for all other Registrants. Deferred gains and losses related to interest rate derivatives are expected to be amortized into earnings through 2051 for Southern Company, Alabama Power, and Georgia Power, 2028 for Mississippi Power, and 2046 for Southern Company Gas.

Foreign Currency Derivatives

Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI.

At March 31, 2022, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(87)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	(24)
Southern Power	564		3.78%	500		1.85%	June 2026	(19)
Southern Power total	$	1,241		€	1,100			$	(43)
Southern Company	$	2,717		€	2,350			$	(130)

The estimated pre-tax losses related to Southern Power's foreign currency derivatives accounted for as cash flow hedges expected to be reclassified from accumulated OCI to earnings for the 12-month period ending March 31, 2023 are $17 million.

Derivative Financial Statement Presentation and Amounts

The Registrants enter into derivative contracts that may contain certain provisions that permit intra-contract netting of derivative receivables and payables for routine billing and offsets related to events of default and settlements. Southern Company and certain subsidiaries also utilize master netting agreements to mitigate exposure to counterparty credit risk. These agreements may contain provisions that permit netting across product lines and against cash collateral. The fair value amounts of derivative assets and liabilities on the balance sheets are presented net to the extent that there are netting arrangements or similar agreements with the counterparties.

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	381	$	1	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	116		6		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	497	$	7	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	28	$	2	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	5		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	17		3		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		136		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		59		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		71		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	50	$	271	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	16	$	2	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	17	$	2	$	10	$	4
Gross amounts recognized	$	564	$	280	$	238	$	153
Gross amounts offset(a)	(45)		(9)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	519	$	271	$	213	$	125

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	87	$	—	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	41		2		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	128	$	2	$	55	$	11
Gross amounts offset	(2)		(2)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	126	$	—	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	150	$	—	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	29		1		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	179	$	1	$	75	$	8
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	$	12	$	—	$	—	$	—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	12	$	—	$	—	$	—
Gross amounts recognized	$	191	$	1	$	75	$	8
Gross amounts offset	(1)		(1)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	190	$	—	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	94	$	—	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	44		2		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	138	$	2	$	56	$	5
Gross amounts offset	(2)		(2)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	136	$	—	$	52	$	1

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	3	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	3		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		35		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		8		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	6	$	43	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	2	$	—	$	1	$	—
Gross amounts recognized	$	8	$	43	$	4	$	16
Gross amounts offset	—		—		—		—
Net amounts recognized in the Balance Sheets	$	8	$	43	$	4	$	16

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	49	$	1	$	15	$	12
Other deferred charges and assets/Other deferred credits and liabilities	3		—		—		—
Total derivatives designated as hedging instruments for regulatory purposes	$	52	$	1	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	25	$	2	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	27	$	38	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	14	$	1	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	15	$	1	$	9	$	4
Gross amounts recognized	$	94	$	40	$	35	$	27
Gross amounts offset(a)	(40)		(4)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	54	$	36	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $36 million and $3 million at March 31, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

Energy-related derivatives not designated as hedging instruments were immaterial for the traditional electric operating companies at March 31, 2022. There were no such instruments for the traditional electric operating companies at December 31, 2021.

At March 31, 2022 and December 31, 2021, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows:

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet
Derivative Category and Balance Sheet Location	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Company Gas
	(in millions)
At March 31, 2022:
Energy-related derivatives:
Other regulatory liabilities, current	$	353	$	87	$	150	$	94	$	22
Other regulatory liabilities, deferred	111		39		28		42		2
Total energy-related derivative gains (losses)	$	464	$	126	$	178	$	136	$	24
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	42	$	5
Interest rate derivatives	9		3
Foreign currency derivatives	(28)		(47)
Fair value hedges(*):
Foreign currency derivatives	4		—
Total	$	27	$	(39)
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	12	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	5	$	4
Foreign currency derivatives	(28)		(47)
Total	$	(23)	$	(43)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	37	$	1

(*)Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives designated as cash flow hedging instruments on accumulated OCI were immaterial for the other Registrants.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		(3)
Total depreciation and amortization	892		871
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(462)		(450)
Gain (loss) on interest rate cash flow hedges(a)	(7)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Gain (loss) on interest rate fair value hedges(b)	(123)		(10)
Total other income (expense), net	145		58
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Gain (loss) on foreign currency fair value hedges	(24)		—
Amount excluded from effectiveness testing recognized in earnings	(4)		—
Southern Power
Total depreciation and amortization	$	120	$	119
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(37)		(38)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Total other income (expense), net	2		7
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Southern Company Gas
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		—
Total interest expense, net of amounts capitalized	(61)		(60)
Gain (loss) on interest rate cash flow hedges(a)	(1)		—
Gain (loss) on interest rate fair value hedges(b)	(36)		—

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income for energy-related derivatives and interest rate derivatives were immaterial for the traditional electric operating companies.

At March 31, 2022 and December 31, 2021, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges:

	Carrying Amount of the Hedged Item				Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item
Balance Sheet Location of Hedged Items	At March 31, 2022		At December 31, 2021		At March 31, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,136)	$	(3,280)	$	126	$	9
Southern Company Gas
Long-term debt	$	(459)	$	(493)	$	37	$	2

For the three months ended March 31, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	2	$	(17)
	Cost of natural gas	21		7
Total derivatives in non-designated hedging relationships		$	23	$	(10)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

For the three months ended March 31, 2022 and 2021, the pre-tax effects of interest rate derivatives not designated as hedging instruments were immaterial for Southern Company and Southern Company Gas and the pre-tax effects of energy-related derivatives not designated as hedging instruments were immaterial for all other Registrants.

Contingent Features

The Registrants do not have any credit arrangements that would require material changes in payment schedules or terminations as a result of a credit rating downgrade. There are certain derivatives that could require collateral, but not accelerated payment, in the event of various credit rating changes of certain Southern Company subsidiaries. At March 31, 2022, the Registrants had no collateral posted with derivative counterparties to satisfy these arrangements.

For the applicable Registrants, the fair value of interest rate and energy-related derivative liabilities with contingent features and the maximum potential collateral requirements arising from the credit-risk-related contingent features, at a rating below BBB- and/or Baa3, were immaterial at March 31, 2022. The maximum potential collateral requirements arising from the credit-risk-related contingent features for the traditional electric operating companies and Southern Power include certain agreements that could require collateral in the event that one or more Southern Company power pool participants has a credit rating change to below investment grade. Following the sale of Gulf Power to NextEra Energy, Inc., Gulf Power has continued participating in the Southern Company power pool; however, the parties currently expect this participation to end during the third quarter 2022.

Generally, collateral may be provided by a Southern Company guaranty, letter of credit, or cash. If collateral is required, fair value amounts recognized for the right to reclaim cash collateral or the obligation to return cash collateral are not offset against fair value amounts recognized for derivatives executed with the same counterparty.

Alabama Power and Southern Power maintain accounts with certain regional transmission organizations to facilitate financial derivative transactions and they may be required to post collateral based on the value of the positions in these accounts and the associated margin requirements. At March 31, 2022, cash collateral posted in these accounts was immaterial. Southern Company Gas maintains accounts with brokers or the clearing houses of certain exchanges to facilitate financial derivative transactions. Based on the value of the positions in these accounts and the associated margin requirements, Southern Company Gas may be required to deposit cash into these accounts. At March 31, 2022, cash collateral held on deposit in broker margin accounts was $36 million.

The Registrants are exposed to losses related to financial instruments in the event of counterparties' nonperformance. The Registrants only enter into agreements and material transactions with counterparties that have investment grade credit ratings by Moody's and S&P or with counterparties who have posted collateral to cover potential credit exposure. The Registrants have also established risk management policies and controls to determine and monitor the creditworthiness of counterparties in order to mitigate their exposure to counterparty credit risk.

Southern Company Gas uses established credit policies to determine and monitor the creditworthiness of counterparties, including requirements to post collateral or other credit security, as well as the quality of pledged collateral. Collateral or credit security is most often in the form of cash or letters of credit from an investment-grade financial institution, but may also include cash or U.S. government securities held by a trustee. Prior to entering a physical transaction, Southern Company Gas assigns its counterparties an internal credit rating and credit limit based on the counterparties' Moody's, S&P, and Fitch ratings, commercially available credit reports, and audited financial statements. Southern Company Gas may require counterparties to pledge additional collateral when deemed necessary.

Southern Company Gas utilizes netting agreements whenever possible to mitigate exposure to counterparty credit risk. Netting agreements enable Southern Company Gas to net certain assets and liabilities by counterparty across product lines and against cash collateral, provided the netting and cash collateral agreements include such provisions. While the amounts due from, or owed to, counterparties are settled net, they are recorded on a gross basis on the balance sheet as energy marketing receivables and energy marketing payables.

The Registrants do not anticipate a material adverse effect on their respective financial statements as a result of counterparty nonperformance.

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Acquisitions and Dispositions

3 Months Ended

Mar. 31, 2022

Business Combination and Asset Acquisition [Abstract]

Acquisitions and Dispositions

ACQUISITIONS AND DISPOSITIONSSee Note 15 to the financial statements in Item 8 of the Form 10-K for additional information.

Southern Power

Construction Projects

During the three months ended March 31, 2022, Southern Power completed construction of and placed in service the remaining 40 MWs of the Tranquillity battery energy storage facility and the remaining 15 MWs of the Garland battery energy storage facility.

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Three Months Ended March 31, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

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Segment and Related Information

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Segment and Related Information

SEGMENT AND RELATED INFORMATION

Southern Company

The primary businesses of the Southern Company system are electricity sales by the traditional electric operating companies and Southern Power and the distribution of natural gas by Southern Company Gas. The traditional electric operating companies are vertically integrated utilities providing electric service in three Southeastern states. Southern Power develops, constructs, acquires, owns, and manages power generation assets, including renewable energy and battery energy storage projects, and sells electricity at market-based rates in the wholesale market. Southern Company Gas distributes natural gas through its natural gas distribution utilities and is involved in several other complementary businesses including gas pipeline investments and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' other businesses also included wholesale gas services.

Southern Company's reportable business segments are the sale of electricity by the traditional electric operating companies, the sale of electricity in the competitive wholesale market by Southern Power, and the sale of natural gas and other complementary products and services by Southern Company Gas. Revenues from sales by Southern Power to the traditional electric operating companies were $105 million and $81 million for the three months ended March 31, 2022 and 2021, respectively. Revenues from sales of natural gas from Southern Company Gas to the traditional electric operating companies were immaterial for both periods presented. Revenues from sales of natural gas from Southern Company Gas to Southern Power were $12 million for the three months ended March 31, 2021, which represented sales from Sequent prior to its sale. The "All Other" column includes the Southern Company parent entity, which does not allocate operating expenses to business segments. Also, this category includes segments below the quantitative threshold for separate disclosure. These segments include providing distributed energy and resilience solutions and deploying microgrids for commercial, industrial, governmental, and utility customers, as well as investments in telecommunications and, for the three months ended March 31, 2021, leveraged lease projects. All other inter-segment revenues are not material.

Financial data for business segments and products and services for the three months ended March 31, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At March 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	90,460		13,766		(627)		103,599		23,377		4,236		(2,573)		128,639
Three Months Ended March 31, 2021
Operating revenues	$	3,764	$	440	$	(87)	$	4,117	$	1,694	$	134	$	(35)	$	5,910
Segment net income (loss)(a)(b)(c)	756		97		—		853		398		(108)		(8)		1,135
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes a pre-tax charge of $48 million ($36 million after tax) at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	3,613	$	664	$	232	$	4,509
Three Months Ended March 31, 2021	3,342		545		230		4,117

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	1,791	$	—	$	243	$	24	$	2,058
Three Months Ended March 31, 2021	1,192		298		195		9		1,694

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Southern Company Gas

Southern Company Gas manages its business through three reportable segments – gas distribution operations, gas pipeline investments, and gas marketing services. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' reportable segments also included wholesale gas services. The non-reportable segments are combined and presented as all other. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information on the sale of Sequent.

Gas distribution operations is the largest component of Southern Company Gas' business and includes natural gas local distribution utilities that construct, manage, and maintain intrastate natural gas pipelines and gas distribution facilities in four states.

Gas pipeline investments consists of joint ventures in natural gas pipeline investments including a 50% interest in SNG and a 50% joint ownership interest in the Dalton Pipeline. These natural gas pipelines enable the provision of diverse sources of natural gas supplies to the customers of Southern Company Gas. Gas pipeline investments also includes a 20% ownership interest in the PennEast Pipeline project, which was cancelled in September 2021. See Note 7 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

Through July 1, 2021, wholesale gas services provided natural gas asset management and/or related logistics services for each of Southern Company Gas' utilities except Nicor Gas as well as for non-affiliated companies. Additionally, wholesale gas services engaged in natural gas storage and gas pipeline arbitrage and related activities.

Gas marketing services provides natural gas marketing to end-use customers primarily in Georgia and Illinois through SouthStar.

The all other column includes segments and subsidiaries that fall below the quantitative threshold for separate disclosure, including storage and fuels operations.

Business segment financial data for the three months ended March 31, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(*)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	—	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income (loss)	214		29		—		66		309		10		—		319
Total assets at March 31, 2022	21,034		1,473		—		1,640		24,147		12,017		(12,787)		23,377
Three Months Ended March 31, 2021
Operating revenues	$	1,200	$	8	$	298	$	195	$	1,701	$	7	$	(14)	$	1,694
Segment net income (loss)	183		29		126		56		394		4		—		398
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three months ended March 31, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2021	$	2,588	$	63	$	2,651	$	2,353	$	298

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Introduction (Policies)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Accounting

The condensed quarterly financial statements of each Registrant included herein have been prepared by such Registrant, without audit, pursuant to the rules and regulations of the SEC. The Condensed Balance Sheets at December 31, 2021 have been derived from the audited financial statements of each Registrant. In the opinion of each Registrant's management, the information regarding such Registrant furnished herein reflects all adjustments, which, except as otherwise disclosed, are of a normal recurring nature, necessary to present fairly the results of operations for the periods ended March 31, 2022 and 2021. Certain information and footnote disclosures normally included in annual financial statements prepared in accordance with GAAP have been condensed or omitted pursuant to such rules and regulations, although each Registrant believes that the disclosures regarding such Registrant are adequate to make the information presented not misleading. Disclosures which would substantially duplicate the disclosures in the Form 10-K and details which have not changed significantly in amount or composition since the filing of the Form 10-K are generally omitted from this Quarterly Report on Form 10-Q unless specifically required by GAAP. Therefore, these Condensed Financial Statements should be read in conjunction with the financial statements and the notes thereto included in the Form 10-K. Due to the seasonal variations in the demand for energy and other factors, operating results for the periods presented are not necessarily indicative of the operating results to be expected for the full year.

Reclassifications

Certain prior year data presented in the financial statements have been reclassified to conform to the current year presentation. These reclassifications had no impact on the overall results of operations, financial position, or cash flows of any Registrant.

Goodwill

Goodwill is not amortized, but is subject to an annual impairment test during the fourth quarter of each year, or more frequently if impairment indicators arise.

Natural Gas for Sale

Natural Gas for Sale

With the exception of Nicor Gas, Southern Company Gas records natural gas inventories on a WACOG basis. For any declines in market prices below the WACOG considered to be other than temporary, an adjustment is recorded to reduce the value of natural gas inventories to market value. Nicor Gas' natural gas inventory is carried at cost on a LIFO basis. Inventory decrements occurring during the year that are restored prior to year end are charged to cost of natural gas at the estimated annual replacement cost. Inventory decrements that are not restored prior to year end are charged to cost of natural gas at the actual LIFO cost of the inventory layers liquidated.

Valuation Methodologies

Valuation Methodologies

The energy-related derivatives primarily consist of exchange-traded and over-the-counter financial products for natural gas and physical power products, including, from time to time, basis swaps. These are standard products used within the energy industry and are valued using the market approach. The inputs used are mainly from observable market sources, such as forward natural gas prices, power prices, implied volatility, and overnight index swap interest rates. Interest rate derivatives are also standard over-the-counter products that are valued using observable market data and assumptions commonly used by market participants. The fair value of interest rate derivatives reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future interest rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and occasionally, implied volatility of interest rate options. The fair value of cross-currency swaps reflects the net present value of expected payments and receipts under the swap agreement based on the market's expectation of future foreign currency exchange rates. Additional inputs to the net present value calculation may include the contract terms, counterparty credit risk, and discount rates. The interest rate derivatives and cross-currency swaps are categorized as Level 2 under Fair Value Measurements as these inputs are based on observable data and valuations of similar instruments. See Note (J) for additional information on how these derivatives are used.

For fair value measurements of the investments within the nuclear decommissioning trusts and the non-qualified deferred compensation trusts, external pricing vendors are designated for each asset class with each security specifically assigned a primary pricing source. For investments held within commingled funds, fair value is determined at the end of each business day through the net asset value, which is established by obtaining the underlying securities' individual prices from the primary pricing source. A market price secured from the primary source vendor is then evaluated by management in its valuation of the assets within the trusts. As a general approach, fixed income market pricing vendors gather market data (including indices and market research reports) and integrate relative credit information, observed market movements, and sector news into proprietary pricing models, pricing systems, and mathematical tools. Dealer quotes and other market information, including live trading levels and pricing analysts' judgments, are also obtained when available.

The NRC requires licensees of commissioned nuclear power reactors to establish a plan for providing reasonable assurance of funds for future decommissioning. See Note 6 to the financial statements under "Nuclear Decommissioning" in Item 8 of the Form 10-K for additional information.

Southern Power has contingent payment obligations related to certain acquisitions whereby it is primarily obligated to make generation-based payments to the seller, which commenced at the commercial operation of the respective facility and continue through 2026. The obligations are categorized as Level 3 under Fair Value Measurements as the fair value is determined using significant unobservable inputs for the forecasted facility generation in MW-hours, as well as other inputs such as a fixed dollar amount per MW-hour, and a discount rate.

Derivatives

The Registrants are exposed to market risks, including commodity price risk, interest rate risk, weather risk, and occasionally foreign currency exchange rate risk. To manage the volatility attributable to these exposures, each company nets its exposures, where possible, to take advantage of natural offsets and enters into various derivative transactions for the remaining exposures pursuant to each company's policies in areas such as counterparty exposure and risk management practices. Prior to the sale of Sequent on July 1, 2021, Southern Company Gas' wholesale gas operations used various contracts in its commercial activities that generally met the definition of derivatives. For the traditional electric operating companies, Southern Power, and Southern Company Gas' other businesses, each company's policy is that derivatives are to be used primarily for hedging purposes and mandates strict adherence to all applicable risk management policies. Derivative positions are monitored using techniques including, but not limited to, market valuation, value at risk, stress testing, and sensitivity analysis. Derivative instruments are recognized at fair value in the balance sheets as either assets or liabilities and are presented on a net basis. See Note (I) for additional fair value information. In the statements of cash flows, any cash impacts of settled energy-related and interest rate derivatives are recorded as operating activities. Any cash impacts of settled foreign currency derivatives are classified as operating or financing activities to correspond with the classification of the hedged interest or principal, respectively. See Note 1 to the financial statements under "Financial Instruments" in Item 8 of the Form 10-K for additional information. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information regarding the sale of Sequent.

Energy-Related Derivatives

The Subsidiary Registrants enter into energy-related derivatives to hedge exposures to electricity, natural gas, and other fuel price changes. However, due to cost-based rate regulations and other various cost recovery mechanisms, the traditional electric operating companies and the natural gas distribution utilities have limited exposure to market volatility in energy-related commodity prices. Each of the traditional electric operating companies and certain of the natural gas distribution utilities of Southern Company Gas manage fuel-hedging programs, implemented per the guidelines of their respective state PSCs or other applicable state regulatory agencies, through the use of financial derivative contracts, which are expected to continue to mitigate price volatility. The traditional electric operating companies (with respect to wholesale generating capacity) and Southern Power have limited exposure to market volatility in energy-related commodity prices because their long-term sales contracts shift substantially all fuel cost responsibility to the purchaser. However, the traditional electric operating companies and Southern Power may be exposed to market volatility in energy-related commodity prices to the extent any uncontracted capacity is used to sell electricity. Southern Company Gas retains exposure to price changes that can, in a volatile energy market, be material and can adversely affect its results of operations.

Southern Company Gas also enters into weather derivative contracts as economic hedges in the event of warmer-than-normal weather. Exchange-traded options are carried at fair value, with changes reflected in operating revenues. Non-exchange-traded options are accounted for using the intrinsic value method. Changes in the intrinsic value for non-exchange-traded contracts are reflected in operating revenues.

Energy-related derivative contracts are accounted for under one of three methods:

•Regulatory Hedges – Energy-related derivative contracts designated as regulatory hedges relate primarily to the traditional electric operating companies' and the natural gas distribution utilities' fuel-hedging programs, where gains and losses are initially recorded as regulatory liabilities and assets, respectively, and then are included in fuel expense as the underlying fuel is used in operations and ultimately recovered through an approved cost recovery mechanism.

•Cash Flow Hedges – Gains and losses on energy-related derivatives designated as cash flow hedges (which are mainly used to hedge anticipated purchases and sales) are initially deferred in accumulated OCI before being recognized in the statements of income in the same period and in the same income statement line item as the earnings effect of the hedged transactions.

•Not Designated – Gains and losses on energy-related derivative contracts that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

Some energy-related derivative contracts require physical delivery as opposed to financial settlement, and this type of derivative is both common and prevalent within the electric and natural gas industries. When an energy-related derivative contract is settled physically, any cumulative unrealized gain or loss is reversed and the contract price is recognized in the respective line item representing the actual price of the underlying goods being delivered.

Interest Rate Derivatives

Southern Company and certain subsidiaries may enter into interest rate derivatives to hedge exposure to changes in interest rates. Derivatives related to existing variable rate securities or forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and presented on the same income statement line item as the earnings effect of the hedged transactions. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item. Fair value gains or losses on derivatives that are not designated or fail to qualify as hedges are recognized in the statements of income as incurred.

Foreign Currency Derivatives

Southern Company and certain subsidiaries, including Southern Power, may enter into foreign currency derivatives to hedge exposure to changes in foreign currency exchange rates, such as that arising from the issuance of debt denominated in a currency other than U.S. dollars. Derivatives related to forecasted transactions are accounted for as cash flow hedges where the derivatives' fair value gains or losses are recorded in OCI and are reclassified into earnings at the same time and on the same income statement line as the earnings effect of the hedged transactions, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Derivatives related to existing fixed rate securities are accounted for as fair value hedges, where the derivatives' fair value gains or losses and hedged items' fair value gains or losses are both recorded directly to earnings on the same income statement line item, including foreign currency gains or losses arising from changes in the U.S. currency exchange rates. Southern Company has elected to exclude the cross-currency basis spread from the assessment of effectiveness in the fair value hedges of its foreign currency risk and record any difference between the change in the fair value of the excluded components and the amounts recognized in earnings as a component of OCI.

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Introduction (Tables)

3 Months Ended

Mar. 31, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Schedule of Goodwill

Goodwill at March 31, 2022 and December 31, 2021 was as follows:

	Goodwill
	(in millions)
Southern Company	$	5,280
Southern Company Gas:
Gas distribution operations	$	4,034
Gas marketing services	981
Southern Company Gas total	$	5,015

Schedule of Other Intangible Assets, Indefinite-Lived

Other intangible assets were as follows:

	At March 31, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(152)	$	60	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(114)		276		390		(109)		281
Other	11		(10)		1		11		(10)		1
Total other intangible assets subject to amortization	$	677	$	(317)	$	360	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	752	$	(317)	$	435	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(114)	$	276	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(132)	$	24	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(148)	$	34	$	182	$	(145)	$	37

Schedule of Other Intangible Assets, Finite-Lived

Other intangible assets were as follows:

	At March 31, 2022						At December 31, 2021
	Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net		Gross Carrying Amount		Accumulated Amortization		Other Intangible Assets, Net
	(in millions)						(in millions)
Southern Company
Other intangible assets subject to amortization:
Customer relationships	$	212	$	(152)	$	60	$	212	$	(150)	$	62
Trade names	64		(41)		23		64		(38)		26
PPA fair value adjustments	390		(114)		276		390		(109)		281
Other	11		(10)		1		11		(10)		1
Total other intangible assets subject to amortization	$	677	$	(317)	$	360	$	677	$	(307)	$	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75		—		75		75		—		75
Total other intangible assets	$	752	$	(317)	$	435	$	752	$	(307)	$	445
Southern Power
Other intangible assets subject to amortization:
PPA fair value adjustments	$	390	$	(114)	$	276	$	390	$	(109)	$	281
Southern Company Gas
Other intangible assets subject to amortization:
Gas marketing services
Customer relationships	$	156	$	(132)	$	24	$	156	$	(130)	$	26
Trade names	26		(16)		10		26		(15)		11
Total other intangible assets subject to amortization	$	182	$	(148)	$	34	$	182	$	(145)	$	37

Schedule of Amortization of Other Intangible Assets

Amortization associated with other intangible assets was as follows:

	Three Months Ended
	March 31, 2022
	(in millions)
Southern Company(a)	$	10
Southern Power(b)	5
Southern Company Gas	3

(a)Includes $5 million recorded as a reduction to operating revenues.

(b)Recorded as a reduction to operating revenues.

Schedule of Restrictions on Cash and Cash Equivalents

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,662	$	1,798	$	130	$	107	$	31	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,673	$	1,829	$	139	$	135	$	33	$	48

(a)For Southern Power, restricted cash reflects $9 million and $10 million at March 31, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects restricted cash held as collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

Schedule of Cash and Cash Equivalents

The following table provides a reconciliation of cash, cash equivalents, and restricted cash reported within the condensed balance sheets that total to the amount shown in the condensed statements of cash flows for the applicable Registrants:

	Southern Company				Southern Power				Southern Company Gas
	March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021		March 31, 2022		December 31, 2021
	(in millions)
Cash and cash equivalents	$	1,662	$	1,798	$	130	$	107	$	31	$	45
Restricted cash(a):
Other current assets	2		2		—		—		2		2
Other deferred charges and assets	9		29		9		29		—		—
Total cash, cash equivalents, and restricted cash(b)	$	1,673	$	1,829	$	139	$	135	$	33	$	48

(a)For Southern Power, restricted cash reflects $9 million and $10 million at March 31, 2022 and December 31, 2021, respectively, held to fund estimated construction completion costs at the Deuel Harvest wind facility and $19 million at December 31, 2021 related to tax equity contributions restricted until the Garland battery energy storage facility achieved final contracted capacity. For Southern Company Gas, reflects restricted cash held as collateral for workers' compensation, life insurance, and long-term disability insurance.

(b)Total may not add due to rounding.

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Regulatory Matters (Tables)

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Schedule of Cost Recovery Clauses

The recovery balances for certain retail regulatory clauses of the traditional electric operating companies and Southern Company Gas at March 31, 2022 and December 31, 2021 were as follows:

Regulatory Clause	Balance Sheet Line Item	March 31, 2022		December 31, 2021
		(in millions)
Alabama Power
Rate CNP Compliance	Other regulatory assets, deferred	$	12	$	16
Rate CNP PPA	Other regulatory assets, deferred	84		84
Retail Energy Cost Recovery(*)	Other regulatory assets, deferred	46		126
Georgia Power
Fuel Cost Recovery	Deferred under recovered fuel clause revenues	$	494	$	410
Mississippi Power
Fuel Cost Recovery	Other customer accounts receivable	$	16	$	4
Ad Valorem Tax	Other regulatory assets, current	12		12
	Other regulatory assets, deferred	33		37
Southern Company Gas
Natural Gas Cost Recovery	Natural gas cost under recovery	$	306	$	266
	Other regulatory assets, deferred	44		207
	Other regulatory liabilities, current	13		—

(*)In accordance with an Alabama PSC order issued on February 1, 2022, Alabama Power applied $126 million of its 2021 Rate RSE refund to reduce the Rate ECR under recovered balance.

Nuclear Construction Cost and Schedule

Georgia Power's approximate proportionate share of the remaining estimated capital cost to complete Plant Vogtle Units 3 and 4, including contingency, through the end of the first quarter 2023 and the fourth quarter 2023, respectively, is as follows:

	(in millions)
Base project capital cost forecast(a)(b)	$	10,294
Construction contingency estimate	107
Total project capital cost forecast(a)(b)	10,401
Net investment at March 31, 2022(b)	(8,715)
Remaining estimate to complete	$	1,686

(a)Includes approximately $590 million of costs that are not shared with the other Vogtle Owners and approximately $440 million of incremental costs under the cost-sharing and tender provisions of the joint ownership agreements described below. Excludes financing costs expected to be capitalized through AFUDC of approximately $377 million, of which $221 million had been accrued through March 31, 2022.

(b)Net of $1.7 billion received from Toshiba under the Guarantee Settlement Agreement and approximately $188 million in related customer refunds.

Schedule of Infrastructure Replacement Programs and Capital Projects

Capital expenditures incurred under specific infrastructure replacement programs and capital projects during the first three months of 2022 were as follows:

Utility	Program	Three Months Ended March 31, 2022
		(in millions)
Nicor Gas	Investing in Illinois	$	51
Virginia Natural Gas	Steps to Advance Virginia's Energy	14
Atlanta Gas Light	System Reinforcement Rider	14
Chattanooga Gas	Pipeline Replacement Program	1
Total		$	80

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Revenue from Contracts with Customers and Lease Income (Tables)

3 Months Ended

Mar. 31, 2022

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

The following table disaggregates revenue from contracts with customers for the three months ended March 31, 2022 and 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Operating revenues
Retail electric revenues
Residential	$	1,525	$	634	$	821	$	70	$	—	$	—
Commercial	1,178		375		738		65		—		—
Industrial	727		323		334		70		—		—
Other	26		4		20		2		—		—
Total retail electric revenues	3,456		1,336		1,913		207		—		—
Natural gas distribution revenues
Residential	1,016		—		—		—		—		1,016
Commercial	270		—		—		—		—		270
Transportation	337		—		—		—		—		337
Industrial	32		—		—		—		—		32
Other	129		—		—		—		—		129
Total natural gas distribution revenues	1,784		—		—		—		—		1,784
Wholesale electric revenues
PPA energy revenues	342		59		32		3		251		—
PPA capacity revenues	134		39		12		3		81		—
Non-PPA revenues	58		64		9		102		73		—
Total wholesale electric revenues	534		162		53		108		405		—
Other natural gas revenues
Gas marketing services	243		—		—		—		—		243
Other natural gas revenues	16		—		—		—		—		16
Total natural gas revenues	259		—		—		—		—		259
Other revenues	225		48		95		9		8		—
Total revenue from contracts with customers	6,258		1,546		2,061		324		413		2,043
Other revenue sources(a)	390		103		147		11		126		15
Total operating revenues	$	6,648	$	1,649	$	2,208	$	335	$	539	$	2,058

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Operating revenues
Retail electric revenues
Residential	$	1,468	$	628	$	776	$	64	$	—	$	—
Commercial	1,117		372		686		59		—		—
Industrial	668		320		284		64		—		—
Other	24		5		17		2		—		—
Total retail electric revenues	3,277		1,325		1,763		189		—		—
Natural gas distribution revenues
Residential	614		—		—		—		—		614
Commercial	170		—		—		—		—		170
Transportation	288		—		—		—		—		288
Industrial	16		—		—		—		—		16
Other	97		—		—		—		—		97
Total natural gas distribution revenues	1,185		—		—		—		—		1,185
Wholesale electric revenues
PPA energy revenues	212		43		13		4		156		—
PPA capacity revenues	119		29		13		3		75		—
Non-PPA revenues	67		32		9		88		61		—
Total wholesale electric revenues	398		104		35		95		292		—
Other natural gas revenues
Wholesale gas services	1,590		—		—		—		—		1,590
Gas marketing services	194		—		—		—		—		194
Other natural gas revenues	7		—		—		—		—		7
Total natural gas revenues	1,791		—		—		—		—		1,791
Other revenues	249		46		113		8		4		—
Total revenue from contracts with customers	6,900		1,475		1,911		292		296		2,976
Other revenue sources(a)	1,306		84		59		15		144		1,014
Other adjustments(b)	(2,296)		—		—		—		—		(2,296)
Total operating revenues	$	5,910	$	1,559	$	1,970	$	307	$	440	$	1,694

(a)Other revenue sources relate to revenues from customers accounted for as derivatives and leases, alternative revenue programs at Southern Company Gas, and cost recovery mechanisms and revenues that meet other scope exceptions for revenues from contracts with customers at the traditional electric operating companies.

(b)Other adjustments relate to the cost of Southern Company Gas' energy and risk management activities. Wholesale gas services revenues are presented net of the related costs of those activities on the statement of income. See Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K and Note (L) under "Southern Company Gas" for information on the sale of Sequent and components of wholesale gas services' operating revenues, respectively.

Schedule of Contract Balances

The following table reflects the closing balances of receivables, contract assets, and contract liabilities related to revenues from contracts with customers at March 31, 2022 and December 31, 2021:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Accounts Receivable
At March 31, 2022	$	2,571	$	616	$	695	$	85	$	128	$	865
At December 31, 2021	2,504		589		736		73		149		753
Contract Assets
At March 31, 2022	$	81	$	2	$	31	$	—	$	—	$	—
At December 31, 2021	117		2		63		—		1		—
Contract Liabilities
At March 31, 2022	$	72	$	3	$	13	$	2	$	1	$	—
At December 31, 2021	57		4		14		—		1		—

Schedule of Remaining Performance Obligations

Revenues from contracts with customers related to these performance obligations remaining at March 31, 2022 are expected to be recognized as follows:

	2022 (remaining)		2023		2024		2025		2026		Thereafter
	(in millions)
Southern Company	$	529	$	459	$	351	$	321	$	307	$	2,345
Alabama Power	24		24		7		5		—		—
Georgia Power	55		55		26		22		11		21
Southern Power	252		294		310		294		299		2,339

Schedule of Lease Income

Lease income for the three months ended March 31, 2022 and 2021 is as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
For the Three Months Ended March 31, 2022
Lease income - interest income on sales-type leases	$	6	$	—	$	—	$	4	$	2	$	—
Lease income - operating leases	51		20		8		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	141	$	20	$	8	$	4	$	113	$	9
For the Three Months Ended March 31, 2021
Lease income - interest income on sales-type leases	$	3	$	—	$	—	$	3	$	—	$	—
Lease income - operating leases	55		21		10		—		21		9
Variable lease income	84		—		—		—		90		—
Total lease income	$	142	$	21	$	10	$	3	$	111	$	9

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Consolidated Entities and Equity Method Investments (Tables)

3 Months Ended

Mar. 31, 2022

Regulated Operations [Abstract]

Schedule of Equity Method Investments

The carrying amounts of Southern Company Gas' equity method investments at March 31, 2022 and December 31, 2021 and related earnings from those investments for the three months ended March 31, 2022 and 2021 were as follows:

Investment Balance	March 31, 2022		December 31, 2021
	(in millions)
SNG	$	1,138	$	1,129
Other(*)	40		44
Total	$	1,178	$	1,173

(*)Balance at March 31, 2022 reflects a $4 million distribution from PennEast Pipeline.

Schedule of Earnings (Loss) from Equity Method Investments

	Three Months Ended March 31,
Earnings from Equity Method Investments	2022		2021
	(in millions)
SNG	$	39	$	38
Other(*)	1		3
Total	$	40	$	41

(*)Earnings primarily result from AFUDC equity recorded by the project entity.

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Financing (Tables)

3 Months Ended

Mar. 31, 2022

Debt Disclosure [Abstract]

Schedule of Credit Arrangements

At March 31, 2022, committed credit arrangements with banks were as follows:

	Expires
Company	2022		2024		2025		2026		Total		Unused		Expires within One Year
	(in millions)
Southern Company parent	$	—	$	—	$	—	$	2,000	$	2,000	$	1,998	$	—
Alabama Power	—		550		—		700		1,250		1,250		—
Georgia Power	—		—		—		1,750		1,750		1,726		—
Mississippi Power	—		150		125		—		275		255		—
Southern Power(a)	—		—		—		600		600		568		—
Southern Company Gas(b)	250		—		—		1,500		1,750		1,747		250
SEGCO	30		—		—		—		30		30		30
Southern Company	$	280	$	700	$	125	$	6,550	$	7,655	$	7,574	$	280

(a)Does not include Southern Power Company's two $75 million continuing letter of credit facilities for standby letters of credit, expiring in 2023 and 2025, respectively, of which $11 million and $19 million, respectively, was unused at March 31, 2022. Southern Power's subsidiaries are not parties to its bank credit arrangements or letter of credit facilities.

(b)Southern Company Gas, as the parent entity, guarantees the obligations of Southern Company Gas Capital, which is the borrower of $800 million of the arrangement expiring in 2026 and all $250 million of the arrangement expiring in 2022. Southern Company Gas' committed credit arrangement expiring in 2026 also includes $700 million for which Nicor Gas is the borrower and which is restricted for working capital needs of Nicor Gas. Pursuant to the multi-year credit arrangement expiring in 2026, the allocations between Southern Company Gas Capital and Nicor Gas may be adjusted.

Schedule of Shares Used to Compute Diluted Earnings Per Share

Shares used to compute diluted earnings per share were as follows:

	Three Months Ended March 31,
	2022	2021
	(in millions)
As reported shares	1,063	1,060
Effect of stock-based compensation	6	6
Diluted shares	1,069	1,066

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Retirement Benefits (Tables)

3 Months Ended

Mar. 31, 2022

Retirement Benefits [Abstract]

Schedule of Pension Plans and Postretirement Plans

Components of the net periodic benefit costs for the three months ended March 31, 2022 and 2021 are presented in the following tables.

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2022
Pension Plans
Service cost	$	103	$	25	$	26	$	4	$	2	$	9
Interest cost	102		24		31		5		2		7
Expected return on plan assets	(316)		(77)		(99)		(15)		(4)		(22)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	60		16		18		3		1		2
Net periodic pension cost (income)	$	(51)	$	(12)	$	(24)	$	(3)	$	1	$	(1)
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	10		3		4		—		—		1
Expected return on plan assets	(20)		(8)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	1

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas
	(in millions)
Three Months Ended March 31, 2021
Pension Plans
Service cost	$	109	$	26	$	28	$	4	$	2	$	9
Interest cost	87		20		26		4		1		6
Expected return on plan assets	(298)		(72)		(94)		(14)		(3)		(21)
Amortization:
Prior service costs	—		—		—		—		—		(1)
Regulatory asset	—		—		—		—		—		4
Net loss	78		21		25		4		1		3
Net periodic pension cost (income)	$	(24)	$	(5)	$	(15)	$	(2)	$	1	$	—
Postretirement Benefits
Service cost	$	6	$	1	$	2	$	—	$	—	$	—
Interest cost	8		2		3		—		—		1
Expected return on plan assets	(19)		(7)		(7)		—		—		(2)
Amortization:
Regulatory asset	—		—		—		—		—		2
Net (gain)/loss	1		—		1		—		—		(1)
Net periodic postretirement benefit cost (income)	$	(4)	$	(4)	$	(1)	$	—	$	—	$	—

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Fair Value Measurements (Tables)

3 Months Ended

Mar. 31, 2022

Fair Value Disclosures [Abstract]

Schedule of Assets and Liabilities Measured at Fair Value

At March 31, 2022, assets and liabilities measured at fair value on a recurring basis during the period, together with their associated level of the fair value hierarchy, were as follows:

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Southern Company
Assets:
Energy-related derivatives(a)	$	74	$	473	$	—	$	—	$	547
Interest rate derivatives	—		17		—		—		17
Investments in trusts:(b)(c)
Domestic equity	754		202		—		—		956
Foreign equity	143		167		—		—		310
U.S. Treasury and government agency securities	—		290		—		—		290
Municipal bonds	—		53		—		—		53
Pooled funds – fixed income	—		10		—		—		10
Corporate bonds	1		490		—		—		491
Mortgage and asset backed securities	—		88		—		—		88
Private equity	—		—		—		156		156
Cash and cash equivalents	3		—		—		—		3
Other	42		25		—		—		67
Cash equivalents	1,182		17		—		—		1,199
Other investments	9		32		—		—		41
Total	$	2,208	$	1,864	$	—	$	156	$	4,228
Liabilities:
Energy-related derivatives(a)	$	3	$	7	$	—	$	—	$	10
Interest rate derivatives	—		139		—		—		139
Foreign currency derivatives	—		130		—		—		130
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	3	$	289	$	14	$	—	$	306

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Alabama Power
Assets:
Energy-related derivatives	$	—	$	128	$	—	$	—	$	128
Nuclear decommissioning trusts:(b)
Domestic equity	452		193		—		—		645
Foreign equity	143		—		—		—		143
U.S. Treasury and government agency securities	—		21		—		—		21
Municipal bonds	—		2		—		—		2
Corporate bonds	1		253		—		—		254
Mortgage and asset backed securities	—		20		—		—		20
Private equity	—		—		—		156		156
Other	14		—		—		—		14
Cash equivalents	1,129		17		—		—		1,146
Other investments	—		32		—		—		32
Total	$	1,739	$	666	$	—	$	156	$	2,561
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Georgia Power
Assets:
Energy-related derivatives	$	—	$	179	$	—	$	—	$	179
Interest rate derivatives	—		12		—		—		12
Nuclear decommissioning trusts:(b)(c)
Domestic equity	302		1		—		—		303
Foreign equity	—		165		—		—		165
U.S. Treasury and government agency securities	—		269		—		—		269
Municipal bonds	—		51		—		—		51
Corporate bonds	—		237		—		—		237
Mortgage and asset backed securities	—		68		—		—		68
Other	28		25		—		—		53
Total	$	330	$	1,007	$	—	$	—	$	1,337
Liabilities:
Energy-related derivatives	$	—	$	1	$	—	$	—	$	1

	Fair Value Measurements Using:
At March 31, 2022	Quoted Prices in Active Markets for Identical Assets (Level 1)		Significant Other Observable Inputs (Level 2)		Significant Unobservable Inputs (Level 3)		Net Asset Value as a Practical Expedient (NAV)		Total
	(in millions)
Mississippi Power
Assets:
Energy-related derivatives	$	—	$	138	$	—	$	—	$	138
Liabilities:
Energy-related derivatives	$	—	$	2	$	—	$	—	$	2
Southern Power
Assets:
Energy-related derivatives	$	—	$	8	$	—	$	—	$	8
Liabilities:
Foreign currency derivatives	$	—	$	43	$	—	$	—	$	43
Contingent consideration	—		—		14		—		14
Other	—		13		—		—		13
Total	$	—	$	56	$	14	$	—	$	70
Southern Company Gas
Assets:
Energy-related derivatives(a)	$	74	$	20	$	—	$	—	$	94
Non-qualified deferred compensation trusts:
Domestic equity	—		8		—		—		8
Foreign equity	—		2		—		—		2
Pooled funds – fixed income	—		10		—		—		10
Cash equivalents	3		—		—		—		3
Total	$	77	$	40	$	—	$	—	$	117
Liabilities:
Energy-related derivatives(a)	$	3	$	1	$	—	$	—	$	4
Interest rate derivatives	—		36		—		—		36
Total	$	3	$	37	$	—	$	—	$	40

(a)Excludes cash collateral of $36 million.

(b)Excludes receivables related to investment income, pending investment sales, payables related to pending investment purchases, and currencies. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

(c)Includes investment securities pledged to creditors and collateral received and excludes payables related to the securities lending program. At March 31, 2022, approximately $72 million of the fair market value of Georgia Power's nuclear decommissioning trust funds' securities were on loan to creditors under the funds' managers' securities lending program. See Note 6 to the financial statements in Item 8 of the Form 10-K for additional information.

Schedule of Increase (Decrease) In Fair Value Of Funds

The fair value of the funds, including reinvested interest and dividends and excluding the funds' expenses, increased (decreased) by the amounts shown in the table below for the three months ended March 31, 2022 and 2021. The changes were recorded as a change to the regulatory assets and liabilities related to AROs for Georgia Power and Alabama Power, respectively.

Fair value increases (decreases)	Three Months Ended March 31, 2022		Three Months Ended March 31, 2021
	(in millions)
Southern Company	$	(150)	$	39
Alabama Power	(67)		41
Georgia Power	(83)		(2)

Schedule of Financial Instruments for which Carrying Amount Did Not Equal Fair Value

At March 31, 2022, other financial instruments for which the carrying amount did not equal fair value were as follows:

	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Power		Southern Company Gas(*)
	(in billions)
Long-term debt, including securities due within one year:
Carrying amount	$	51.6	$	9.8	$	13.2	$	1.5	$	3.7	$	6.9
Fair value	51.9		10.0		13.5		1.5		3.8		6.9

(*)The long-term debt of Southern Company Gas is recorded at amortized cost, including the fair value adjustments at the effective date of the 2016 merger with Southern Company. Southern Company Gas amortizes the fair value adjustments over the remaining lives of the respective bonds, the latest being through 2043.

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Derivatives (Tables)

3 Months Ended

Mar. 31, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Energy-Related Derivatives

At March 31, 2022, the net volume of energy-related derivative contracts for natural gas positions, together with the longest hedge date over which the respective entity is hedging its exposure to the variability in future cash flows for forecasted transactions and the longest non-hedge date for derivatives not designated as hedges, were as follows:

	Net Purchased mmBtu	Longest Hedge Date	Longest Non-Hedge Date
	(in millions)
Southern Company(*)	279	2030	2025
Alabama Power	65	2025	—
Georgia Power	75	2024	—
Mississippi Power	71	2026	—
Southern Power	4	2030	—
Southern Company Gas(*)	64	2024	2025

(*)Southern Company Gas' derivative instruments include both long and short natural gas positions. A long position is a contract to purchase natural gas and a short position is a contract to sell natural gas. Southern Company Gas' volume represents the net of long natural gas positions of 66.2 million mmBtu and short natural gas positions of 2.6 million mmBtu at March 31, 2022, which is also included in Southern Company's total volume.

Schedule of Interest Rate Derivatives

At March 31, 2022, the following interest rate derivatives were outstanding:

	Notional Amount		Interest Rate Received	Weighted Average Interest Rate Paid	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)					(in millions)
Cash Flow Hedges of Forecasted Debt
Georgia Power	$	200	1.87%	—	February 2032	$	8
Georgia Power	100		2.27%	—	November 2051	4
Cash Flow Hedges of Existing Debt
Southern Company parent	100		2.58%	—	April 2027	(1)
Fair Value Hedges of Existing Debt
Southern Company parent	400		1.75%	1-month LIBOR + 0.68%	March 2028	(29)
Southern Company parent	1,000		3.70%	1-month LIBOR + 2.36%	April 2030	(69)
Southern Company Gas	500		1.75%	1-month LIBOR + 0.38%	January 2031	(35)
Southern Company	$	2,300				$	(122)

Schedule of Foreign Currency Derivatives

At March 31, 2022, the following foreign currency derivatives were outstanding:

	Pay Notional		Pay Rate	Receive Notional		Receive Rate	Hedge Maturity Date	Fair Value Gain (Loss) at March 31, 2022
	(in millions)			(in millions)				(in millions)
Fair Value Hedges of Existing Debt
Southern Company parent	$	1,476	3.39%	€	1,250	1.88%	September 2027	$	(87)
Cash Flow Hedges of Existing Debt
Southern Power	$	677	2.95%	€	600	1.00%	June 2022	$	(24)
Southern Power	564		3.78%	500		1.85%	June 2026	(19)
Southern Power total	$	1,241		€	1,100			$	(43)
Southern Company	$	2,717		€	2,350			$	(130)

Schedule of Derivative Category and Balance Sheet Location

The fair value of energy-related derivatives, interest rate derivatives, and foreign currency derivatives was reflected in the balance sheets as follows:

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	381	$	1	$	129	$	30
Other deferred charges and assets/Other deferred credits and liabilities	116		6		72		6
Total derivatives designated as hedging instruments for regulatory purposes	$	497	$	7	$	201	$	36
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	28	$	2	$	7	$	5
Other deferred charges and assets/Other deferred credits and liabilities	5		—		1		—
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	17		3		19		—
Other deferred charges and assets/Other deferred credits and liabilities	—		136		—		29
Foreign currency derivatives:
Assets from risk management activities/Other current liabilities	—		59		—		39
Other deferred charges and assets/Other deferred credits and liabilities	—		71		—		40
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	50	$	271	$	27	$	113
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	16	$	2	$	9	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	17	$	2	$	10	$	4
Gross amounts recognized	$	564	$	280	$	238	$	153
Gross amounts offset(a)	(45)		(9)		(25)		(28)
Net amounts recognized in the Balance Sheets(b)	$	519	$	271	$	213	$	125

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Alabama Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Other current assets/Other current liabilities	$	87	$	—	$	30	$	9
Other deferred charges and assets/Other deferred credits and liabilities	41		2		25		2
Total derivatives designated as hedging instruments for regulatory purposes	$	128	$	2	$	55	$	11
Gross amounts offset	(2)		(2)		(5)		(5)
Net amounts recognized in the Balance Sheets	$	126	$	—	$	50	$	6
Georgia Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	150	$	—	$	54	$	6
Other deferred charges and assets/Other deferred credits and liabilities	29		1		21		2
Total derivatives designated as hedging instruments for regulatory purposes	$	179	$	1	$	75	$	8
Derivatives designated as hedging instruments in cash flow and fair value hedges
Interest rate derivatives:
Assets from risk management activities/Other current liabilities	$	12	$	—	$	—	$	—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	12	$	—	$	—	$	—
Gross amounts recognized	$	191	$	1	$	75	$	8
Gross amounts offset	(1)		(1)		(8)		(8)
Net amounts recognized in the Balance Sheets	$	190	$	—	$	67	$	—
Mississippi Power
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	94	$	—	$	30	$	3
Other deferred charges and assets/Other deferred credits and liabilities	44		2		26		2
Total derivatives designated as hedging instruments for regulatory purposes	$	138	$	2	$	56	$	5
Gross amounts offset	(2)		(2)		(4)		(4)
Net amounts recognized in the Balance Sheets	$	136	$	—	$	52	$	1

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Power
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Other current assets/Other current liabilities	$	3	$	—	$	2	$	—
Other deferred charges and assets/Other deferred credits and liabilities	3		—		1		—
Foreign currency derivatives:
Other current assets/Other current liabilities	—		35		—		16
Other deferred charges and assets/Other deferred credits and liabilities	—		8		—		—
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	6	$	43	$	3	$	16
Derivatives not designated as hedging instruments
Energy-related derivatives:
Other current assets/Other current liabilities	$	2	$	—	$	1	$	—
Gross amounts recognized	$	8	$	43	$	4	$	16
Gross amounts offset	—		—		—		—
Net amounts recognized in the Balance Sheets	$	8	$	43	$	4	$	16

	At March 31, 2022				At December 31, 2021
Derivative Category and Balance Sheet Location	Assets		Liabilities		Assets		Liabilities
	(in millions)				(in millions)
Southern Company Gas
Derivatives designated as hedging instruments for regulatory purposes
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	49	$	1	$	15	$	12
Other deferred charges and assets/Other deferred credits and liabilities	3		—		—		—
Total derivatives designated as hedging instruments for regulatory purposes	$	52	$	1	$	15	$	12
Derivatives designated as hedging instruments in cash flow and fair value hedges
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	25	$	2	$	5	$	5
Other deferred charges and assets/Other deferred credits and liabilities	2		—		—		—
Interest rate derivatives:
Assets from risk management activities/Liabilities from risk management activities-current	—		—		6		—
Other deferred charges and assets/Other deferred credits and liabilities	—		36		—		6
Total derivatives designated as hedging instruments in cash flow and fair value hedges	$	27	$	38	$	11	$	11
Derivatives not designated as hedging instruments
Energy-related derivatives:
Assets from risk management activities/Other current liabilities	$	14	$	1	$	8	$	4
Other deferred charges and assets/Other deferred credits and liabilities	1		—		1		—
Total derivatives not designated as hedging instruments	$	15	$	1	$	9	$	4
Gross amounts recognized	$	94	$	40	$	35	$	27
Gross amounts offset(a)	(40)		(4)		(8)		(11)
Net amounts recognized in the Balance Sheets(b)	$	54	$	36	$	27	$	16

(a)Gross amounts offset include cash collateral held on deposit in broker margin accounts of $36 million and $3 million at March 31, 2022 and December 31, 2021, respectively.

(b)Net amounts of derivative instruments outstanding exclude immaterial premium and intrinsic value associated with weather derivatives for both periods presented.

Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses)

At March 31, 2022 and December 31, 2021, the pre-tax effects of unrealized derivative gains (losses) arising from energy-related derivative instruments designated as regulatory hedging instruments and deferred were as follows:

Regulatory Hedge Unrealized Gain (Loss) Recognized in the Balance Sheet
Derivative Category and Balance Sheet Location	Southern Company		Alabama Power		Georgia Power		Mississippi Power		Southern Company Gas
	(in millions)
At March 31, 2022:
Energy-related derivatives:
Other regulatory liabilities, current	$	353	$	87	$	150	$	94	$	22
Other regulatory liabilities, deferred	111		39		28		42		2
Total energy-related derivative gains (losses)	$	464	$	126	$	178	$	136	$	24
At December 31, 2021:
Energy-related derivatives:
Other regulatory assets, current	$	(17)	$	(6)	$	—	$	—	$	(11)
Other regulatory liabilities, current	107		28		48		27		4
Other regulatory liabilities, deferred	65		22		19		24		—
Total energy-related derivative gains (losses)	$	155	$	44	$	67	$	51	$	(7)

Schedule of Pre-Tax Effects of Hedging on AOCI

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on accumulated OCI were as follows:

Gain (Loss) Recognized in OCI on Derivative	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Cash flow hedges:
Energy-related derivatives	$	42	$	5
Interest rate derivatives	9		3
Foreign currency derivatives	(28)		(47)
Fair value hedges(*):
Foreign currency derivatives	4		—
Total	$	27	$	(39)
Georgia Power
Cash flow hedges:
Interest rate derivatives	$	12	$	—
Southern Power
Cash flow hedges:
Energy-related derivatives	$	5	$	4
Foreign currency derivatives	(28)		(47)
Total	$	(23)	$	(43)
Southern Company Gas
Cash flow hedges:
Energy-related derivatives	$	37	$	1

(*)Represents amounts excluded from the assessment of effectiveness for which the difference between changes in fair value and periodic amortization is recorded in OCI.

Schedule of Pre-Tax Effects of Cash Flow and Fair Value Hedging on Income

For the three months ended March 31, 2022 and 2021, the pre-tax effects of cash flow and fair value hedge accounting on income were as follows:

Location and Amount of Gain (Loss) Recognized in Income on Cash Flow and Fair Value Hedging Relationships	For the Three Months Ended March 31,
	2022		2021
	(in millions)
Southern Company
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		(3)
Total depreciation and amortization	892		871
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(462)		(450)
Gain (loss) on interest rate cash flow hedges(a)	(7)		(7)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Gain (loss) on interest rate fair value hedges(b)	(123)		(10)
Total other income (expense), net	145		58
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Gain (loss) on foreign currency fair value hedges	(24)		—
Amount excluded from effectiveness testing recognized in earnings	(4)		—
Southern Power
Total depreciation and amortization	$	120	$	119
Gain (loss) on energy-related cash flow hedges(a)	2		3
Total interest expense, net of amounts capitalized	(37)		(38)
Gain (loss) on foreign currency cash flow hedges(a)	(6)		(6)
Total other income (expense), net	2		7
Gain (loss) on foreign currency cash flow hedges(a)(c)	(25)		(60)
Southern Company Gas
Total cost of natural gas	$	1,095	$	583
Gain (loss) on energy-related cash flow hedges(a)	9		—
Total interest expense, net of amounts capitalized	(61)		(60)
Gain (loss) on interest rate cash flow hedges(a)	(1)		—
Gain (loss) on interest rate fair value hedges(b)	(36)		—

(a)Reclassified from accumulated OCI into earnings.

(b)For fair value hedges, changes in the fair value of the derivative contracts are generally equal to changes in the fair value of the underlying debt and have no material impact on income.

(c)The reclassification from accumulated OCI into other income (expense), net completely offsets currency gains and losses arising from changes in the U.S. currency exchange rates used to record the euro-denominated notes.

Schedule of Cumulative Basis Adjustments for Fair Value Hedges

At March 31, 2022 and December 31, 2021, the following amounts were recorded on the balance sheets related to cumulative basis adjustments for fair value hedges:

	Carrying Amount of the Hedged Item				Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item
Balance Sheet Location of Hedged Items	At March 31, 2022		At December 31, 2021		At March 31, 2022		At December 31, 2021
	(in millions)				(in millions)
Southern Company
Long-term debt	$	(3,136)	$	(3,280)	$	126	$	9
Southern Company Gas
Long-term debt	$	(459)	$	(493)	$	37	$	2

Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income

For the three months ended March 31, 2022 and 2021, the pre-tax effects of energy-related derivatives not designated as hedging instruments on the statements of income of Southern Company and Southern Company Gas were as follows:

		Gain (Loss)
		Three Months Ended March 31,
Derivatives in Non-Designated Hedging Relationships	Statements of Income Location	2022		2021
		(in millions)
Energy-related derivatives:	Natural gas revenues(*)	$	2	$	(17)
	Cost of natural gas	21		7
Total derivatives in non-designated hedging relationships		$	23	$	(10)

(*)Excludes immaterial gains (losses) recorded in natural gas revenues associated with weather derivatives for all periods presented.

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Acquisitions and Dispositions (Tables)

3 Months Ended

Mar. 31, 2022

Business Combination and Asset Acquisition [Abstract]

Schedule of Construction Projects

Project Facility	Resource	Approximate Nameplate Capacity (MW)	Location	COD	PPA Contract Period
Projects Completed During the Three Months Ended March 31, 2022
Garland Solar Storage(a)	Battery energy storage system	88	Kern County, CA	September 2021 through February 2022(b)	20 years
Tranquillity Solar Storage(a)	Battery energy storage system	72	Fresno County, CA	November 2021 through March 2022(c)	20 years

(a)Southern Power consolidates each project's operating results in its financial statements and the tax equity partner and two other partners each own a noncontrolling interest.

(b)The facility has a total capacity of 88 MWs, of which 73 MWs were placed in service in 2021 and 15 MWs were placed in service in February 2022.

(c)The facility has a total capacity of 72 MWs, of which 32 MWs were placed in service in 2021 and 40 MWs were placed in service in March 2022.

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Segment and Related Information (Tables)

3 Months Ended

Mar. 31, 2022

Segment Reporting [Abstract]

Schedule of Financial Data for Business Segments

Financial data for business segments and products and services for the three months ended March 31, 2022 and 2021 was as follows:

	Electric Utilities
	Traditional Electric Operating Companies		Southern Power		Eliminations		Total		Southern Company Gas		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	4,191	$	539	$	(221)	$	4,509	$	2,058	$	123	$	(42)	$	6,648
Segment net income (loss)(a)	774		72		—		846		319		(125)		(8)		1,032
At March 31, 2022
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	90,460		13,766		(627)		103,599		23,377		4,236		(2,573)		128,639
Three Months Ended March 31, 2021
Operating revenues	$	3,764	$	440	$	(87)	$	4,117	$	1,694	$	134	$	(35)	$	5,910
Segment net income (loss)(a)(b)(c)	756		97		—		853		398		(108)		(8)		1,135
At December 31, 2021
Goodwill	$	—	$	2	$	—	$	2	$	5,015	$	263	$	—	$	5,280
Total assets	89,051		13,390		(667)		101,774		23,560		2,975		(775)		127,534

(a)Attributable to Southern Company.

(b)For the traditional electric operating companies, includes a pre-tax charge of $48 million ($36 million after tax) at Georgia Power for estimated losses associated with the construction of Plant Vogtle Units 3 and 4. See Note (B) and Note 2 to the financial statements in Item 8 of the Form 10-K under "Georgia Power – Nuclear Construction" for additional information.

(c)For Southern Power, includes gains on wind turbine equipment contributed to various equity method investments totaling approximately $37 million pre-tax ($28 million after tax). See Note 15 to the financial statements under "Southern Power – Development Projects" in Item 8 of the Form 10-K for additional information.

Business segment financial data for the three months ended March 31, 2022 and 2021 was as follows:

	Gas Distribution Operations		Gas Pipeline Investments		Wholesale Gas Services(*)		Gas Marketing Services		Total		All Other		Eliminations		Consolidated
	(in millions)
Three Months Ended March 31, 2022
Operating revenues	$	1,803	$	8	$	—	$	243	$	2,054	$	16	$	(12)	$	2,058
Segment net income (loss)	214		29		—		66		309		10		—		319
Total assets at March 31, 2022	21,034		1,473		—		1,640		24,147		12,017		(12,787)		23,377
Three Months Ended March 31, 2021
Operating revenues	$	1,200	$	8	$	298	$	195	$	1,701	$	7	$	(14)	$	1,694
Segment net income (loss)	183		29		126		56		394		4		—		398
Total assets at December 31, 2021	20,917		1,467		31		1,556		23,971		12,114		(12,525)		23,560

(*)As a result of the sale of Sequent, wholesale gas services is no longer a reportable segment for the three months ended March 31, 2022. Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. A reconciliation of operating revenues and intercompany revenues is shown in the following table.

	Third Party Gross Revenues		Intercompany Revenues		Total Gross Revenues		Less Gross Gas Costs		Operating Revenues
	(in millions)
Three Months Ended March 31, 2021	$	2,588	$	63	$	2,651	$	2,353	$	298

Schedule of Financial Data for Products and Services

	Electric Utilities' Revenues
	Retail		Wholesale		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	3,613	$	664	$	232	$	4,509
Three Months Ended March 31, 2021	3,342		545		230		4,117

	Southern Company Gas' Revenues
	Gas Distribution Operations		Wholesale Gas Services(*)		Gas Marketing Services		Other		Total
	(in millions)
Three Months Ended March 31, 2022	$	1,791	$	—	$	243	$	24	$	2,058
Three Months Ended March 31, 2021	1,192		298		195		9		1,694

(*)Prior to the sale of Sequent, the revenues for wholesale gas services were netted with costs associated with its energy and risk management activities. See "Southern Company Gas" herein and Note 15 to the financial statements under "Southern Company Gas" in Item 8 of the Form 10-K for additional information.

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Introduction - Schedule of Goodwill (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Goodwill [Line Items]
Goodwill	$ 5,280	$ 5,280
SOUTHERN Co GAS
Goodwill [Line Items]
Goodwill	5,015	5,015
SOUTHERN Co GAS | Gas distribution operations
Goodwill [Line Items]
Goodwill	4,034	4,034
SOUTHERN Co GAS | Gas marketing services
Goodwill [Line Items]
Goodwill	$ 981	$ 981

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Introduction - Schedule of Other Intangible Assets (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Other intangible assets subject to amortization:
Gross Carrying Amount	$ 677	$ 677
Accumulated Amortization	(317)	(307)
Other Intangible Assets, Net	360	370
Other intangible assets not subject to amortization:
Federal Communications Commission licenses	75	75
Total other intangible assets
Gross Carrying Amount	752	752
Accumulated Amortization	(317)	(307)
Other Intangible Assets, Net	435	445
Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	212	212
Accumulated Amortization	(152)	(150)
Other Intangible Assets, Net	60	62
Total other intangible assets
Accumulated Amortization	(152)	(150)
Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	64	64
Accumulated Amortization	(41)	(38)
Other Intangible Assets, Net	23	26
Total other intangible assets
Accumulated Amortization	(41)	(38)
PPA fair value adjustments
Other intangible assets subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(114)	(109)
Other Intangible Assets, Net	276	281
Total other intangible assets
Accumulated Amortization	(114)	(109)
Other
Other intangible assets subject to amortization:
Gross Carrying Amount	11	11
Accumulated Amortization	(10)	(10)
Other Intangible Assets, Net	1	1
Total other intangible assets
Accumulated Amortization	(10)	(10)
SOUTHERN POWER CO
Other intangible assets subject to amortization:
Accumulated Amortization	(114)	(109)
Total other intangible assets
Accumulated Amortization	(114)	(109)
SOUTHERN POWER CO | PPA fair value adjustments
Other intangible assets subject to amortization:
Gross Carrying Amount	390	390
Accumulated Amortization	(114)	(109)
Other Intangible Assets, Net	276	281
Total other intangible assets
Accumulated Amortization	(114)	(109)
SOUTHERN Co GAS
Other intangible assets subject to amortization:
Gross Carrying Amount	182	182
Accumulated Amortization	(148)	(145)
Other Intangible Assets, Net	34	37
Total other intangible assets
Accumulated Amortization	(148)	(145)
Other Intangible Assets, Net	34	37
SOUTHERN Co GAS | Customer relationships
Other intangible assets subject to amortization:
Gross Carrying Amount	156	156
Accumulated Amortization	(132)	(130)
Other Intangible Assets, Net	24	26
Total other intangible assets
Accumulated Amortization	(132)	(130)
SOUTHERN Co GAS | Trade names
Other intangible assets subject to amortization:
Gross Carrying Amount	26	26
Accumulated Amortization	(16)	(15)
Other Intangible Assets, Net	10	11
Total other intangible assets
Accumulated Amortization	$ (16)	$ (15)

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Introduction - Schedule of Amortization of Other Intangible Assets (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 10
Decrease in operating revenues	5
SOUTHERN POWER CO
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	5
SOUTHERN Co GAS
Finite-Lived Intangible Assets [Line Items]
Amortization of intangible assets	$ 3

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Introduction - Schedule of Cash, Cash Equivalents, and Restricted Cash (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2021	Dec. 31, 2020
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	$ 1,662	$ 1,798
Restricted cash:
Total cash, cash equivalents, and restricted cash	1,673	1,829	$ 1,801	$ 1,068
Other current assets
Restricted cash:
Restricted cash	2	2
Other deferred charges and assets
Restricted cash:
Restricted cash	9	29
SOUTHERN POWER CO
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	130	107
Restricted cash:
Total cash, cash equivalents, and restricted cash	139	135	343	182
SOUTHERN POWER CO | Other current assets
Restricted cash:
Restricted cash	0	0
SOUTHERN POWER CO | Other deferred charges and assets
Restricted cash:
Restricted cash	9	29
SOUTHERN POWER CO | Tax Equity Contributions | Garland
Restricted cash:
Restricted cash		19
SOUTHERN POWER CO | Estimated Construction Completion Costs | Deuel Harvest
Restricted cash:
Restricted cash	9	10
SOUTHERN Co GAS
Restricted Cash and Cash Equivalents Items [Line Items]
Cash and cash equivalents	31	45
Restricted cash:
Total cash, cash equivalents, and restricted cash	33	48	$ 311	$ 19
SOUTHERN Co GAS | Other current assets
Restricted cash:
Restricted cash	2	2
SOUTHERN Co GAS | Other deferred charges and assets
Restricted cash:
Restricted cash	$ 0	$ 0

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Introduction - Depreciation and Amortization (Details)		12 Months Ended
	Jan. 01, 2022	Dec. 31, 2021
Maximum | Wind Generating Facility | SOUTHERN POWER CO
Property, Plant and Equipment [Line Items]
Property, plant and equipment, useful life	35 years	30 years

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Regulatory Matters - Schedule of Cost Recovery Clauses (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 306	$ 266
ALABAMA POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Rate CNP Compliance	12	16
Rate CNP PPA	84	84
Retail Energy Cost Recovery	46	126
GEORGIA POWER CO | Other deferred charges and assets
Loss Contingencies [Line Items]
Fuel Cost Recovery	494	410
MISSISSIPPI POWER CO | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Ad Valorem Tax	33	37
MISSISSIPPI POWER CO | Other customer accounts receivable
Loss Contingencies [Line Items]
Fuel Cost Recovery	16	4
MISSISSIPPI POWER CO | Other regulatory assets, current
Loss Contingencies [Line Items]
Ad Valorem Tax	12	12
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Natural gas cost under recovery	306	266
SOUTHERN Co GAS | Other regulatory assets, deferred
Loss Contingencies [Line Items]
Natural gas cost under recovery	44	207
SOUTHERN Co GAS | Other regulatory assets, current
Loss Contingencies [Line Items]
Natural gas cost under recovery	306	266
SOUTHERN Co GAS | Other regulatory liabilities, current
Loss Contingencies [Line Items]
Natural gas cost under recovery	$ 13	$ 0

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Regulatory Matters - GPC Integrated Resource Plan (Details) - GEORGIA POWER CO	3 Months Ended
	Mar. 31, 2022 MW
Public Utilities, General Disclosures [Line Items]
Approved capacity increase (in MWs)	970
Service date extension term	1 year

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Regulatory Matters - GPC Nuclear Construction (Details) - GEORGIA POWER CO - Plant Vogtle Units 3 And 4 $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022 USD ($)	Dec. 31, 2012 utility MW	Aug. 31, 2018
Loss Contingencies [Line Items]
Proportionate ownership share	45.70%
Number of construction units approved | utility		2
Electric generating capacity in mega watts under consortium agreement | MW		1,100
Estimated cost to complete, construction contingency estimate, financing costs	$ 3,400
Estimated cost to complete, construction contingency estimate, financing costs, incurred to date	3,000
Construction contingency estimate	43
Base project capital cost forecast, monthly	60
Monthly AFUDC	$ 40
Percentage of ownership interest required for voting for continuing construction			90.00%
Vogtle Owners
Loss Contingencies [Line Items]
Period of notice required in the event letters of credit are not renewed	30 days
Minimum | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term	3 months
Estimate of possible loss	$ 160
Maximum | COVID-19
Loss Contingencies [Line Items]
Loss contingency, estimate of possible loss, loss of productivity, term	4 months
Estimate of possible loss	$ 200

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Regulatory Matters - GPC Nuclear Construction Cost and Schedule (Details) - GEORGIA POWER CO $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Loss Contingencies [Line Items]
Pre-tax charge to income	$ 440
Plant Vogtle Units 3 And 4
Loss Contingencies [Line Items]
Base project capital cost forecast	10,294
Construction contingency estimate	107
Total project capital cost forecast	10,401
Net investment as of end of the period	(8,715)
Remaining estimate to complete	1,686
Estimated cost to complete, costs not shared with other owners	590
Expected capitalized costs	377
Capitalized interest accrued	221
Plant Vogtle Units 3 And 4 | Twenty Fifth Vogtle Construction Monitoring Report
Loss Contingencies [Line Items]
Guarantor obligations	1,700
Customer refund	$ 188

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Regulatory Matters - GPC Amendments to the Vogtle Joint Ownership Agreements (Details) - Georgia Power - USD ($) $ in Thousands		3 Months Ended
	Jan. 11, 2018	Mar. 31, 2022	Aug. 31, 2018
Public Utilities, General Disclosures [Line Items]
Pre-tax charge to income		$ 440,000
After tax charge to income		328,000
Plant Vogtle Units 3 And 4
Public Utilities, General Disclosures [Line Items]
Production tax credits, aggregate purchase price, maximum		300,000
Preliminary estimated cost to complete		10,401,000
Additional construction capital costs	$ 3,300,000	$ 460,000
Remaining share of construction costs, agreement to pay, percentage		100.00%
Percentage of ownership interest required for voting for continuing construction			90.00%
Percentage of costs, disallowed for recovery		6.00%
Costs disallowed for recovery, period		6 months
Public utilities, extension project schedule, term		1 year
Estimated cost to complete, starting dollar amount		$ 18,380,000
Proportionate ownership share		45.70%
Plant Vogtle Units 3 And 4 | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs		$ 100
Plant Vogtle Units 3 And 4 | Category I
Public Utilities, General Disclosures [Line Items]
Preliminary estimated cost to complete		8,400,000
Additional construction capital costs, threshold		$ 800,000
Plant Vogtle Units 3 And 4 | Category II
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay		55.70%
Additional construction capital costs		$ 80,000
Plant Vogtle Units 3 And 4 | Category II | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay		44.30%
Plant Vogtle Units 3 And 4 | Category II | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold		$ 800,000
Plant Vogtle Units 3 And 4 | Category II | Maximum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold		$ 1,600,000
Plant Vogtle Units 3 And 4 | Category III
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay		65.70%
Additional construction capital costs		$ 100,000
Plant Vogtle Units 3 And 4 | Category III | Vogtle Owners
Public Utilities, General Disclosures [Line Items]
Percentage of construction costs, responsibility to pay		34.30%
Plant Vogtle Units 3 And 4 | Category III | Minimum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold		$ 1,600,000
Plant Vogtle Units 3 And 4 | Category III | Maximum
Public Utilities, General Disclosures [Line Items]
Additional construction capital costs, threshold		$ 2,100,000

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Regulatory Matters - GPC Nuclear Construction Regulatory Matters (Details) - Plant Vogtle Units 3 And 4 - Georgia Power $ in Millions							3 Months Ended	6 Months Ended	12 Months Ended
	Feb. 17, 2022 USD ($)	Jan. 01, 2022 USD ($)	Jan. 01, 2021	Jan. 01, 2020	Jan. 11, 2018 USD ($)	Jan. 01, 2016	Mar. 31, 2022 USD ($)	Jun. 30, 2021 USD ($) report	Dec. 31, 2023 USD ($)	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2009 USD ($)	Jun. 30, 2018 USD ($)	Dec. 31, 2013
Public Utilities, General Disclosures [Line Items]
Estimated in-service capital cost												$ 4,418
Financing costs collected, net of tax							$ 2,800
Requested decrease in tariff		$ 78
Additional construction capital costs					$ 3,300		$ 460
Payments for contractor settlement agreement					300
Amendment to estimated in-service capital cost					$ 5,680
Retail rate of return on common equity														10.95%
Public utilities, approved return on equity percentage			5.30%	8.30%		10.00%
Public utilities, approved return on equity, monthly percentage decrease							0.10%
Return on equity reduction, negative impact on earnings											$ 270
Increase to base capital cost forecast not seeking recovery													$ 700
Twenty Fourth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Cost settlement agreement revised forecast, net of payments							$ 7,300
Twenty Fifth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Number of approved construction management reports | report								25
Requested capital construction costs								$ 7,900
Guarantor obligations							1,700
Customer refund							$ 188
Twenty Sixth Vogtle Construction Monitoring Report
Public Utilities, General Disclosures [Line Items]
Requested capital construction costs	$ 584
Scenario, Forecast
Public Utilities, General Disclosures [Line Items]
Return on equity reduction, negative impact on earnings									$ 265	$ 300

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Regulatory Matters - MPC (Details) - MISSISSIPPI POWER CO - USD ($) $ in Millions	Apr. 13, 2022	Mar. 15, 2022	Jun. 08, 2021
Loss Contingencies [Line Items]
Approved rate increase, percentage		1.90%
Approved rate increase (decrease)			$ 18
Subsequent Event
Loss Contingencies [Line Items]
Approved rate increase (decrease)	$ 5

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Regulatory Matters - GAS Schedule of Infrastructure Replacement Programs and Capital Projects (Details) - SOUTHERN Co GAS $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 80
Investing in Illinois
Public Utilities, General Disclosures [Line Items]
Capital expenditures	51
Steps to Advance Virginia's Energy
Public Utilities, General Disclosures [Line Items]
Capital expenditures	14
System Reinforcement Rider
Public Utilities, General Disclosures [Line Items]
Capital expenditures	14
Pipeline Replacement Program
Public Utilities, General Disclosures [Line Items]
Capital expenditures	$ 1

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Contingencies - General Litigation Matters (Details) - Pending Litigation $ in Millions				1 Months Ended	12 Months Ended
	Mar. 11, 2022 USD ($)	Feb. 07, 2022 claim	Oct. 08, 2021 claim	Mar. 31, 2019 plaintiff	Dec. 31, 2018 USD ($) plaintiff defendant	Mar. 09, 2022 claim	Dec. 31, 2017 claim
Shareholder Derivative Lawsuits
Loss Contingencies [Line Items]
Pending number of claims							2
Settlement expense | $	$ 4.5
GEORGIA POWER CO | Class Action Lawsuit
Loss Contingencies [Line Items]
Pending number of claims						4
Complaints filed		4	3
MISSISSIPPI POWER CO | Purported Violations of Mississippi Consumer Protection Act
Loss Contingencies [Line Items]
Number of plaintiffs | plaintiff					10
Number of defendants | defendant					3
Number of additional plaintiffs | plaintiff				4
Underpayment of refunds | $					$ 23.5

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Contingencies - Environmental Remediation (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
GEORGIA POWER CO
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 16	$ 17
SOUTHERN Co GAS
Loss Contingencies [Line Items]
Environmental remediation liability, current and former sites	$ 249	$ 249

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Revenue from Contracts with Customers and Lease Income - Schedule of Disaggregation of Revenue (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 6,258	$ 6,900
Total operating revenues	6,648	5,910
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	3,613	3,342
Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3,456	3,277
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,525	1,468
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,178	1,117
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	727	668
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	26	24
Natural Gas
Disaggregation of Revenue [Line Items]
Total operating revenues	2,058	1,694
Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,784	1,185
Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,016	614
Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	270	170
Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	337	288
Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	32	16
Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	129	97
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	259	1,791
Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		1,590
Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	243	194
Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16	7
Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	390	1,306
Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		(2,296)
Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	664	545
Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	534	398
PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	342	212
PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	134	119
Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	58	67
Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	225	249
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,546	1,475
Total operating revenues	1,649	1,559
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	1,379	1,352
ALABAMA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,336	1,325
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	634	628
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	375	372
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	323	320
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4	5
ALABAMA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0
ALABAMA POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
ALABAMA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	103	84
ALABAMA POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0
ALABAMA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	162	104
ALABAMA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	59	43
ALABAMA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	39	29
ALABAMA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	64	32
ALABAMA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	48	46
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2,061	1,911
Total operating revenues	2,208	1,970
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	2,017	1,787
GEORGIA POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,913	1,763
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	821	776
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	738	686
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	334	284
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	20	17
GEORGIA POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0
GEORGIA POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
GEORGIA POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	147	59
GEORGIA POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0
GEORGIA POWER CO | Wholesale Electric
Disaggregation of Revenue [Line Items]
Total operating revenues	66	43
GEORGIA POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	53	35
GEORGIA POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	32	13
GEORGIA POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	12	13
GEORGIA POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	9	9
GEORGIA POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	95	113
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	324	292
Total operating revenues	335	307
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total operating revenues	217	204
MISSISSIPPI POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	207	189
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	70	64
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	65	59
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	70	64
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2	2
MISSISSIPPI POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0
MISSISSIPPI POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
MISSISSIPPI POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	11	15
MISSISSIPPI POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0
MISSISSIPPI POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	108	95
MISSISSIPPI POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	4
MISSISSIPPI POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	3	3
MISSISSIPPI POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	102	88
MISSISSIPPI POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	9	8
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	413	296
Total operating revenues	539	440
SOUTHERN POWER CO | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		0
SOUTHERN POWER CO | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN POWER CO | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	126	144
SOUTHERN POWER CO | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		0
SOUTHERN POWER CO | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	405	292
SOUTHERN POWER CO | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	251	156
SOUTHERN POWER CO | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	81	75
SOUTHERN POWER CO | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	73	61
SOUTHERN POWER CO | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	8	4
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	2,043	2,976
Total operating revenues	2,058	1,694
SOUTHERN Co GAS | Retail electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Natural gas distribution revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,784	1,185
SOUTHERN Co GAS | Residential
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	1,016	614
SOUTHERN Co GAS | Commercial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	270	170
SOUTHERN Co GAS | Transportation
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	337	288
SOUTHERN Co GAS | Industrial
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	32	16
SOUTHERN Co GAS | Other
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	129	97
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	259	1,791
SOUTHERN Co GAS | Wholesale gas services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers		1,590
SOUTHERN Co GAS | Gas marketing services
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	243	194
SOUTHERN Co GAS | Other natural gas revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16	7
SOUTHERN Co GAS | Other revenue sources
Disaggregation of Revenue [Line Items]
Other revenues	15	1,014
SOUTHERN Co GAS | Other adjustments
Disaggregation of Revenue [Line Items]
Other revenues		(2,296)
SOUTHERN Co GAS | Wholesale electric revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | PPA energy revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | PPA capacity revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Non-PPA revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	0	0
SOUTHERN Co GAS | Other revenues
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Contract Balances (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Accounts Receivable	$ 2,571	$ 2,504
Contract Assets	81	117
Contract Liabilities	72	57
ALABAMA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	616	589
Contract Assets	2	2
Contract Liabilities	3	4
GEORGIA POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	695	736
Contract Assets	31	63
Contract Liabilities	13	14
MISSISSIPPI POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	85	73
Contract Assets	0	0
Contract Liabilities	2	0
SOUTHERN POWER CO
Disaggregation of Revenue [Line Items]
Accounts Receivable	128	149
Contract Assets	0	1
Contract Liabilities	1	1
SOUTHERN Co GAS
Disaggregation of Revenue [Line Items]
Accounts Receivable	865	753
Contract Assets	0	0
Contract Liabilities	$ 0	$ 0

XML

Revenue from Contracts with Customers and Lease Income - Narrative (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Disaggregation of Revenue [Line Items]
Contract assets	$ 81	$ 117
Contract liabilities	72	57
Unregulated Distributed Generation
Disaggregation of Revenue [Line Items]
Contract assets	47	50
Contract liabilities	$ 54	$ 39

XML

Revenue from Contracts with Customers and Lease Income - Schedule of Remaining Performance Obligations (Details) $ in Millions	Mar. 31, 2022 USD ($)
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 529
Performance obligation, expected timing of satisfaction	3 months
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 459
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 351
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 321
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 307
Performance obligation, expected timing of satisfaction	1 year
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,345
Performance obligation, expected timing of satisfaction
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24
Performance obligation, expected timing of satisfaction	3 months
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 24
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 7
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 5
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction	1 year
ALABAMA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 0
Performance obligation, expected timing of satisfaction
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 55
Performance obligation, expected timing of satisfaction	3 months
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 55
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 26
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 22
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 11
Performance obligation, expected timing of satisfaction	1 year
GEORGIA POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 21
Performance obligation, expected timing of satisfaction
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2022-04-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 252
Performance obligation, expected timing of satisfaction	3 months
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2023-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 294
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2024-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 310
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2025-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 294
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2026-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 299
Performance obligation, expected timing of satisfaction	1 year
SOUTHERN POWER CO | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date [Axis]: 2027-01-01
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction [Line Items]
Revenue, remaining performance obligation	$ 2,339
Performance obligation, expected timing of satisfaction

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Revenue from Contracts with Customers and Lease Income - Schedule of Lease Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	$ 6	$ 3
Lease income - operating leases	51	55
Variable lease income	84	84
Total lease income	141	142
ALABAMA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	20	21
Variable lease income	0	0
Total lease income	20	21
GEORGIA POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	8	10
Variable lease income	0	0
Total lease income	8	10
MISSISSIPPI POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	4	3
Lease income - operating leases	0	0
Variable lease income	0	0
Total lease income	4	3
SOUTHERN POWER CO
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	2	0
Lease income - operating leases	21	21
Variable lease income	90	90
Total lease income	113	111
SOUTHERN Co GAS
Lessor, Lease, Description [Line Items]
Lease income - interest income on sales-type leases	0	0
Lease income - operating leases	9	9
Variable lease income	0	0
Total lease income	$ 9	$ 9

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Consolidated Entities and Equity Method Investments - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($) investor	Dec. 31, 2021 USD ($)
Schedule of Equity Method Investments [Line Items]
Assets	$ 128,639	$ 127,534
Liabilities	95,719	94,967
Equity investments in unconsolidated subsidiaries	1,293	1,282
Southern Power
Schedule of Equity Method Investments [Line Items]
Assets	13,766	13,390
Liabilities	7,210	6,792
Equity investments in unconsolidated subsidiaries	56	86
Proceeds from sale of equity method investments	$ 31
SP Solar Holdings I, LP | Southern Power
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	67.00%
SP Solar Holdings I, LP | Global Atlantic
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	33.00%
Variable Interest Entity, Primary Beneficiary | SP Solar Holdings I, LP | Southern Power
Schedule of Equity Method Investments [Line Items]
Assets	$ 6,000	6,100
Liabilities	407	408
Noncontrolling interests related to other partners' interests	1,100	1,100
Variable Interest Entity, Primary Beneficiary | SP Wind | Southern Power
Schedule of Equity Method Investments [Line Items]
Assets	2,300	2,300
Liabilities	180	130
Noncontrolling interests related to other partners' interests	$ 41	41
Distribution made to limited partner, cash distributions paid, percentage	60.00%
Number of financial investors | investor	3
Variable Interest Entity, Primary Beneficiary | SP Wind | Financial Investors
Schedule of Equity Method Investments [Line Items]
Distribution made to limited partner, cash distributions paid, percentage	40.00%
Variable Interest Entity, Primary Beneficiary | Other Variable Interest Entities | Southern Power
Schedule of Equity Method Investments [Line Items]
Assets	$ 1,800	1,900
Liabilities	248	263
Noncontrolling interests related to other partners' interests	$ 876	$ 886

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Consolidated Entities and Equity Method Investments - Schedule of Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Dec. 31, 2021
Schedule of Equity Method Investments [Line Items]
Investment Balance	$ 1,293	$ 1,282
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,178	1,173
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Investment Balance	1,138	1,129
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Investment Balance	40	$ 44
SOUTHERN Co GAS | PennEast Pipeline
Schedule of Equity Method Investments [Line Items]
Distribution	$ 4

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Consolidated Entities and Equity Method Investments - Schedule of Earnings (Loss) from Equity Method Investments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 46	$ 45
SOUTHERN Co GAS
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	40	41
SOUTHERN Co GAS | SNG
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	39	38
SOUTHERN Co GAS | Other
Schedule of Equity Method Investments [Line Items]
Earnings from Equity Method Investments	$ 1	$ 3

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Financing - Schedule of Credit Arrangements (Details)	3 Months Ended
	Mar. 31, 2022 USD ($) letter_of_credit
Line of Credit Facility [Line Items]
Expires, 2022	$ 280,000,000
Expires, 2024	700,000,000
Expires, 2025	125,000,000
Expires, 2026	6,550,000,000
Total	7,655,000,000
Unused	7,574,000,000
Expires within One Year	280,000,000
Southern Company parent
Line of Credit Facility [Line Items]
Expires, 2022	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	2,000,000,000
Total	2,000,000,000
Unused	1,998,000,000
Expires within One Year	0
ALABAMA POWER CO
Line of Credit Facility [Line Items]
Expires, 2022	0
Expires, 2024	550,000,000
Expires, 2025	0
Expires, 2026	700,000,000
Total	1,250,000,000
Unused	1,250,000,000
Expires within One Year	0
GEORGIA POWER CO
Line of Credit Facility [Line Items]
Expires, 2022	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	1,750,000,000
Total	1,750,000,000
Unused	1,726,000,000
Expires within One Year	0
MISSISSIPPI POWER CO
Line of Credit Facility [Line Items]
Expires, 2022	0
Expires, 2024	150,000,000
Expires, 2025	125,000,000
Expires, 2026	0
Total	275,000,000
Unused	255,000,000
Expires within One Year	0
SOUTHERN POWER CO
Line of Credit Facility [Line Items]
Expires, 2022	0
Expires, 2024	0
Expires, 2025	0
Expires, 2026	600,000,000
Total	600,000,000
Unused	568,000,000
Expires within One Year	$ 0
Letter of credits not included | letter_of_credit	2
SOUTHERN POWER CO | Continuing Letter of Credit Facility A
Line of Credit Facility [Line Items]
Expires, 2025	$ 75,000,000
Unused	11,000,000
Expires, 2023	75,000,000
SOUTHERN POWER CO | Continuing Letter of Credit Facility B
Line of Credit Facility [Line Items]
Unused	19,000,000
SOUTHERN Co GAS
Line of Credit Facility [Line Items]
Expires, 2022	250,000,000
Expires, 2024	0
Expires, 2025	0
Expires, 2026	1,500,000,000
Total	1,750,000,000
Unused	1,747,000,000
Expires within One Year	250,000,000
SEGCO
Line of Credit Facility [Line Items]
Expires, 2022	30,000,000
Expires, 2024	0
Expires, 2025	0
Expires, 2026	0
Total	30,000,000
Unused	30,000,000
Expires within One Year	30,000,000
Southern Company Gas Capital
Line of Credit Facility [Line Items]
Expires, 2026	800,000,000
Nicor Gas
Line of Credit Facility [Line Items]
Expires, 2026	$ 700,000,000

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Financing - Narrative (Details)	Mar. 31, 2022 USD ($)
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	$ 7,655,000,000
Variable rate pollution control revenue bonds outstanding	1,500,000,000
MISSISSIPPI POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	275,000,000
Variable rate pollution control revenue bonds outstanding	34,000,000
MISSISSIPPI POWER CO | Line of Credit | Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	125,000,000
ALABAMA POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	1,250,000,000
Variable rate pollution control revenue bonds outstanding	789,000,000
GEORGIA POWER CO
Debt Instrument [Line Items]
Line of credit facility, maximum borrowing capacity	1,750,000,000
Variable rate pollution control revenue bonds outstanding	672,000,000
Fixed rate pollution control revenue bonds outstanding	$ 330,000,000

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Financing - Schedule of Shares Used to Compute Diluted Earnings Per Share (Details) - shares shares in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Debt Disclosure [Abstract]
As reported shares (in shares)	1,063	1,060
Effect of stock-based compensation (in shares)	6	6
Diluted shares (in shares)	1,069	1,066

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Income Taxes - Narrative (Details)	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
MISSISSIPPI POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	16.40%	8.40%
SOUTHERN POWER CO
Income Tax Contingency [Line Items]
Effective tax (benefit) rate	(80.00%)	(17.30%)

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Retirement Benefits (Details) - USD ($)	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Pension Plans
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, expected future employer contributions, remainder of fiscal year	$ 0
Pension Plans and Postretirement Plans
Service cost	103,000,000	$ 109,000,000
Interest cost	102,000,000	87,000,000
Expected return on plan assets	(316,000,000)	(298,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	60,000,000	78,000,000
Net periodic pension cost (income)	(51,000,000)	(24,000,000)
Pension Plans | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	25,000,000	26,000,000
Interest cost	24,000,000	20,000,000
Expected return on plan assets	(77,000,000)	(72,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	16,000,000	21,000,000
Net periodic pension cost (income)	(12,000,000)	(5,000,000)
Pension Plans | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	26,000,000	28,000,000
Interest cost	31,000,000	26,000,000
Expected return on plan assets	(99,000,000)	(94,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	18,000,000	25,000,000
Net periodic pension cost (income)	(24,000,000)	(15,000,000)
Pension Plans | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	4,000,000	4,000,000
Interest cost	5,000,000	4,000,000
Expected return on plan assets	(15,000,000)	(14,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	3,000,000	4,000,000
Net periodic pension cost (income)	(3,000,000)	(2,000,000)
Pension Plans | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	2,000,000	2,000,000
Interest cost	2,000,000	1,000,000
Expected return on plan assets	(4,000,000)	(3,000,000)
Amortization:
Prior service costs	0	0
Regulatory asset	0	0
Net (gain)/loss	1,000,000	1,000,000
Net periodic pension cost (income)	1,000,000	1,000,000
Pension Plans | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	9,000,000	9,000,000
Interest cost	7,000,000	6,000,000
Expected return on plan assets	(22,000,000)	(21,000,000)
Amortization:
Prior service costs	(1,000,000)	(1,000,000)
Regulatory asset	4,000,000	4,000,000
Net (gain)/loss	2,000,000	3,000,000
Net periodic pension cost (income)	(1,000,000)	0
Postretirement Benefits
Pension Plans and Postretirement Plans
Service cost	6,000,000	6,000,000
Interest cost	10,000,000	8,000,000
Expected return on plan assets	(20,000,000)	(19,000,000)
Amortization:
Regulatory asset	0	0
Net (gain)/loss		1,000,000
Net periodic pension cost (income)	(4,000,000)	(4,000,000)
Postretirement Benefits | ALABAMA POWER CO
Pension Plans and Postretirement Plans
Service cost	1,000,000	1,000,000
Interest cost	3,000,000	2,000,000
Expected return on plan assets	(8,000,000)	(7,000,000)
Amortization:
Regulatory asset	0	0
Net (gain)/loss		0
Net periodic pension cost (income)	(4,000,000)	(4,000,000)
Postretirement Benefits | GEORGIA POWER CO
Pension Plans and Postretirement Plans
Service cost	2,000,000	2,000,000
Interest cost	4,000,000	3,000,000
Expected return on plan assets	(7,000,000)	(7,000,000)
Amortization:
Regulatory asset	0	0
Net (gain)/loss		1,000,000
Net periodic pension cost (income)	(1,000,000)	(1,000,000)
Postretirement Benefits | MISSISSIPPI POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	0	0
Expected return on plan assets	0	0
Amortization:
Regulatory asset	0	0
Net (gain)/loss		0
Net periodic pension cost (income)	0	0
Postretirement Benefits | SOUTHERN POWER CO
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	0	0
Expected return on plan assets	0	0
Amortization:
Regulatory asset	0	0
Net (gain)/loss		0
Net periodic pension cost (income)	0	0
Postretirement Benefits | SOUTHERN Co GAS
Pension Plans and Postretirement Plans
Service cost	0	0
Interest cost	1,000,000	1,000,000
Expected return on plan assets	(2,000,000)	(2,000,000)
Amortization:
Regulatory asset	2,000,000	2,000,000
Net (gain)/loss		(1,000,000)
Net periodic pension cost (income)	$ 1,000,000	$ 0

XML

Fair Value Measurements - Schedule of Assets and Liabilities Measured at Fair Value (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Assets:
Derivatives	$ 519	$ 213
Liabilities:
Derivatives	271	125
Other	13
Collateral already posted, assets, aggregate fair value	36
Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Other	0
Significant Other Observable Inputs (Level 2)
Liabilities:
Other	13
Significant Unobservable Inputs (Level 3)
Liabilities:
Other	0
ALABAMA POWER CO
Assets:
Derivatives	126	50
Liabilities:
Derivatives	0	6
GEORGIA POWER CO
Assets:
Derivatives	190	67
Investments in trusts	72
Liabilities:
Derivatives	0	0
MISSISSIPPI POWER CO
Assets:
Derivatives	136	52
Liabilities:
Derivatives	0	1
SOUTHERN POWER CO
Assets:
Derivatives	8	4
Liabilities:
Derivatives	43	16
Other	13
SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Other	0
SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Liabilities:
Other	13
SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Liabilities:
Other	0
SOUTHERN Co GAS
Assets:
Derivatives	54	27
Liabilities:
Derivatives	36	16
Total
Collateral already posted, assets, aggregate fair value	36	$ 3
Fair Value, Measurements, Recurring
Assets:
Cash equivalents	1,199
Other investments	41
Total	4,228
Liabilities:
Contingent consideration	14
Total	306
Fair Value, Measurements, Recurring | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	1,182
Other investments	9
Total	2,208
Liabilities:
Contingent consideration	0
Total	3
Fair Value, Measurements, Recurring | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	17
Other investments	32
Total	1,864
Liabilities:
Contingent consideration	0
Total	289
Fair Value, Measurements, Recurring | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	0
Total	0
Liabilities:
Contingent consideration	14
Total	14
Fair Value, Measurements, Recurring | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	156
Fair Value, Measurements, Recurring | Energy-related derivatives
Assets:
Derivatives	547
Liabilities:
Derivatives	10
Fair Value, Measurements, Recurring | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	74
Liabilities:
Derivatives	3
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	473
Liabilities:
Derivatives	7
Fair Value, Measurements, Recurring | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives
Assets:
Derivatives	17
Liabilities:
Derivatives	139
Fair Value, Measurements, Recurring | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	17
Liabilities:
Derivatives	139
Fair Value, Measurements, Recurring | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Domestic equity
Assets:
Investments in trusts	956
Fair Value, Measurements, Recurring | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	754
Fair Value, Measurements, Recurring | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	202
Fair Value, Measurements, Recurring | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Foreign equity
Assets:
Investments in trusts	310
Fair Value, Measurements, Recurring | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	143
Fair Value, Measurements, Recurring | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	167
Fair Value, Measurements, Recurring | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities
Assets:
Investments in trusts	290
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	290
Fair Value, Measurements, Recurring | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Municipal bonds
Assets:
Investments in trusts	53
Fair Value, Measurements, Recurring | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	53
Fair Value, Measurements, Recurring | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Pooled funds – fixed income
Assets:
Investments in trusts	10
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	10
Fair Value, Measurements, Recurring | Pooled funds – fixed income | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Corporate bonds
Assets:
Investments in trusts	491
Fair Value, Measurements, Recurring | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	490
Fair Value, Measurements, Recurring | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Mortgage and asset backed securities
Assets:
Investments in trusts	88
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	88
Fair Value, Measurements, Recurring | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity
Assets:
Investments in trusts	156
Fair Value, Measurements, Recurring | Private equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Private equity | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	156
Fair Value, Measurements, Recurring | Cash and cash equivalents
Assets:
Investments in trusts	3
Fair Value, Measurements, Recurring | Cash and cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	3
Fair Value, Measurements, Recurring | Cash and cash equivalents | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Cash and cash equivalents | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Other
Assets:
Investments in trusts	67
Fair Value, Measurements, Recurring | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	42
Fair Value, Measurements, Recurring | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	25
Fair Value, Measurements, Recurring | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | Foreign currency derivatives
Liabilities:
Derivatives	130
Fair Value, Measurements, Recurring | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	130
Fair Value, Measurements, Recurring | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO
Assets:
Cash equivalents	1,146
Other investments	32
Total	2,561
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Cash equivalents	1,129
Other investments	0
Total	1,739
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Cash equivalents	17
Other investments	32
Total	666
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Cash equivalents	0
Other investments	0
Total	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Net Asset Value as a Practical Expedient (NAV)
Assets:
Total	156
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives
Assets:
Derivatives	128
Liabilities:
Derivatives	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	128
Liabilities:
Derivatives	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity
Assets:
Investments in trusts	645
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	452
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	193
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity
Assets:
Investments in trusts	143
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	143
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities
Assets:
Investments in trusts	21
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	21
Fair Value, Measurements, Recurring | ALABAMA POWER CO | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds
Assets:
Investments in trusts	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	2
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds
Assets:
Investments in trusts	254
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	253
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	20
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity
Assets:
Investments in trusts	156
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Private equity | Net Asset Value as a Practical Expedient (NAV)
Assets:
Investments in trusts	156
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other
Assets:
Investments in trusts	14
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	14
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | ALABAMA POWER CO | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO
Assets:
Total	1,337
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Total	330
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Other Observable Inputs (Level 2)
Assets:
Total	1,007
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Significant Unobservable Inputs (Level 3)
Assets:
Total	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives
Assets:
Derivatives	179
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	179
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives
Assets:
Derivatives	12
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	12
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity
Assets:
Investments in trusts	303
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	302
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	1
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity
Assets:
Investments in trusts	165
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	165
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities
Assets:
Investments in trusts	269
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	269
Fair Value, Measurements, Recurring | GEORGIA POWER CO | U.S. Treasury and government agency securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds
Assets:
Investments in trusts	51
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	51
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Municipal bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds
Assets:
Investments in trusts	237
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	237
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Corporate bonds | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities
Assets:
Investments in trusts	68
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	68
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Mortgage and asset backed securities | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other
Assets:
Investments in trusts	53
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Investments in trusts	28
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Other Observable Inputs (Level 2)
Assets:
Investments in trusts	25
Fair Value, Measurements, Recurring | GEORGIA POWER CO | Other | Significant Unobservable Inputs (Level 3)
Assets:
Investments in trusts	0
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives
Assets:
Derivatives	138
Liabilities:
Derivatives	2
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	138
Liabilities:
Derivatives	2
Fair Value, Measurements, Recurring | MISSISSIPPI POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO
Liabilities:
Contingent consideration	14
Total	70
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Contingent consideration	0
Total	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Other Observable Inputs (Level 2)
Liabilities:
Contingent consideration	0
Total	56
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Significant Unobservable Inputs (Level 3)
Liabilities:
Contingent consideration	14
Total	14
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives
Assets:
Derivatives	8
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	8
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives
Liabilities:
Derivatives	43
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	43
Fair Value, Measurements, Recurring | SOUTHERN POWER CO | Foreign currency derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS
Assets:
Total	117
Liabilities:
Total	40
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Total	77
Liabilities:
Total	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Other Observable Inputs (Level 2)
Assets:
Total	40
Liabilities:
Total	37
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Significant Unobservable Inputs (Level 3)
Assets:
Total	0
Liabilities:
Total	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives
Assets:
Derivatives	94
Liabilities:
Derivatives	4
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Derivatives	74
Liabilities:
Derivatives	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Other Observable Inputs (Level 2)
Assets:
Derivatives	20
Liabilities:
Derivatives	1
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Energy-related derivatives | Significant Unobservable Inputs (Level 3)
Assets:
Derivatives	0
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives
Liabilities:
Derivatives	36
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Other Observable Inputs (Level 2)
Liabilities:
Derivatives	36
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Interest rate derivatives | Significant Unobservable Inputs (Level 3)
Liabilities:
Derivatives	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity
Assets:
Non-qualified deferred compensation trusts	8
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	8
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Domestic equity | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity
Assets:
Non-qualified deferred compensation trusts	2
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	2
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Foreign equity | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income
Assets:
Non-qualified deferred compensation trusts	10
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	10
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Pooled funds – fixed income | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents
Assets:
Non-qualified deferred compensation trusts	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Quoted Prices in Active Markets for Identical Assets (Level 1)
Assets:
Non-qualified deferred compensation trusts	3
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Significant Other Observable Inputs (Level 2)
Assets:
Non-qualified deferred compensation trusts	0
Fair Value, Measurements, Recurring | SOUTHERN Co GAS | Cash equivalents | Significant Unobservable Inputs (Level 3)
Assets:
Non-qualified deferred compensation trusts	$ 0

XML

Fair Value Measurements - Schedule of Increase (Decrease) In Fair Value Of Funds (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ (150)	$ 39
ALABAMA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	(67)	41
GEORGIA POWER CO
Fair Value, Option, Quantitative Disclosures [Line Items]
Increase (decrease) in fair value of funds	$ (83)	$ (2)

XML

Fair Value Measurements - Narrative (Details) - ALABAMA POWER CO - Private equity $ in Millions	Mar. 31, 2022 USD ($)
Fair Value, Investments, Entities that Calculate Net Asset Value Per Share [Line Items]
Fair value	$ 156
Unfunded commitments	$ 84

XML

Fair Value Measurements - Schedule of Financial Instruments for which Carrying Amount did not Equal Fair Value (Details) $ in Millions	Mar. 31, 2022 USD ($)
Long-term debt, including securities due within one year:
Carrying amount	$ 51,600.0
Fair value	51,900.0
ALABAMA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	9,800.0
Fair value	10,000.0
GEORGIA POWER CO
Long-term debt, including securities due within one year:
Carrying amount	13,200.0
Fair value	13,500.0
MISSISSIPPI POWER CO
Long-term debt, including securities due within one year:
Carrying amount	1,500.0
Fair value	1,500.0
SOUTHERN POWER CO
Long-term debt, including securities due within one year:
Carrying amount	3,700.0
Fair value	3,800.0
SOUTHERN Co GAS
Long-term debt, including securities due within one year:
Carrying amount	6,900.0
Fair value	$ 6,900.0

XML

Derivatives - Schedule of Energy-Related Derivatives (Details) - Energy-related, Natural Gas MMBTU in Millions	Mar. 31, 2022 MMBTU
Energy-related derivative contracts
Net Purchased mmBtu	279.0
ALABAMA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	65.0
GEORGIA POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	75.0
MISSISSIPPI POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	71.0
SOUTHERN POWER CO
Energy-related derivative contracts
Net Purchased mmBtu	4.0
SOUTHERN Co GAS
Energy-related derivative contracts
Net Purchased mmBtu	64.0
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Long
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	66.2
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Short
Energy-related derivative contracts
Derivative nonmonetary notional amount net long short position volume	2.6

XML

Derivatives - Narrative (Details) MMBTU in Millions	3 Months Ended
	Mar. 31, 2022 USD ($) MMBTU	Dec. 31, 2021 USD ($)
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	18
Collateral already posted, assets, aggregate fair value	$ 36,000,000
Energy-related, Natural Gas
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	29,000,000
Interest rate derivatives
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	$ (20,000,000)
ALABAMA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	4
GEORGIA POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	6
MISSISSIPPI POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	3
SOUTHERN POWER CO
Derivative [Line Items]
Expected volume of natural gas subject to option to sell back excess gas due to operational constraints | MMBTU	5
Foreign currency cash flow hedge gain (loss) to be reclassified during next 12 months	$ 17,000,000
Registrants | Derivative Counterparties
Derivative [Line Items]
Collateral already posted, assets, aggregate fair value	0
SOUTHERN Co GAS
Derivative [Line Items]
Collateral already posted, assets, aggregate fair value	36,000,000	$ 3,000,000
SOUTHERN Co GAS | Energy-related, Natural Gas
Derivative [Line Items]
Cash flow hedge gain (loss) to be reclassified within twelve months	$ 26,000,000

XML

Derivatives - Schedule of Interest Rate Derivatives (Details) - Interest rate derivatives $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($)
Derivative [Line Items]
Notional Amount	$ 2,300
Fair Value Gain (Loss)	(122)
GEORGIA POWER CO | Cash Flow Hedges of Forecasted Debt | February 2032
Derivative [Line Items]
Notional Amount	$ 200
Interest Rate Received	1.87%
Weighted Average Interest Rate Paid	0.00%
Fair Value Gain (Loss)	$ 8
GEORGIA POWER CO | Cash Flow Hedges of Forecasted Debt | November 2051
Derivative [Line Items]
Notional Amount	$ 100
Interest Rate Received	2.27%
Weighted Average Interest Rate Paid	0.00%
Fair Value Gain (Loss)	$ 4
Southern Company parent | Cash Flow Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 100
Interest Rate Received	2.58%
Weighted Average Interest Rate Paid	0.00%
Fair Value Gain (Loss)	$ (1)
Southern Company parent | Fair Value Hedges of Existing Debt | March 2028
Derivative [Line Items]
Notional Amount	$ 400
Interest Rate Received	1.75%
Fair Value Gain (Loss)	$ (29)
Southern Company parent | Fair Value Hedges of Existing Debt | April 2030
Derivative [Line Items]
Notional Amount	$ 1,000
Interest Rate Received	3.70%
Fair Value Gain (Loss)	$ (69)
SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Notional Amount	$ 500
Interest Rate Received	1.75%
Fair Value Gain (Loss)	$ (35)
London Interbank Offered Rate (LIBOR) | Southern Company parent | Fair Value Hedges of Existing Debt | March 2028
Derivative [Line Items]
Weighted Average Interest Rate Paid	0.68%
London Interbank Offered Rate (LIBOR) | Southern Company parent | Fair Value Hedges of Existing Debt | April 2030
Derivative [Line Items]
Weighted Average Interest Rate Paid	2.36%
London Interbank Offered Rate (LIBOR) | SOUTHERN Co GAS | Fair Value Hedges of Existing Debt
Derivative [Line Items]
Weighted Average Interest Rate Paid	0.38%

XML

Derivatives - Schedule of Foreign Currency Derivatives (Details) - 3 months ended Mar. 31, 2022 - Foreign currency derivatives € in Millions, $ in Millions	USD ($)	EUR (€)
Derivative [Line Items]
Pay Notional	$ 2,717
Receive Notional | €		€ 2,350
Fair Value Gain (Loss)	(130)
Fair Value Hedges of Existing Debt | Southern Company parent
Derivative [Line Items]
Pay Notional	$ 1,476
Pay Rate	3.39%
Receive Notional | €		1,250
Receive Rate	1.88%
Fair Value Gain (Loss)	$ (87)
Cash Flow Hedges of Existing Debt | SOUTHERN POWER CO
Derivative [Line Items]
Pay Notional	1,241
Receive Notional | €		1,100
Fair Value Gain (Loss)	(43)
Cash Flow Hedges of Existing Debt | SOUTHERN POWER CO | June 2022
Derivative [Line Items]
Pay Notional	$ 677
Pay Rate	2.95%
Receive Notional | €		600
Receive Rate	1.00%
Fair Value Gain (Loss)	$ (24)
Cash Flow Hedges of Existing Debt | SOUTHERN POWER CO | June 2026
Derivative [Line Items]
Pay Notional	$ 564
Pay Rate	3.78%
Receive Notional | €		€ 500
Receive Rate	1.85%
Fair Value Gain (Loss)	$ (19)

XML

Derivatives - Schedule of Derivative Category and Balance Sheet Location (Details) - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	$ 564	$ 238
Derivative asset, Gross amounts offset	(45)	(25)
Derivative asset, net amounts recognized in the balance sheets	519	213
Derivative liability, gross amount recognized	280	153
Derivative liability, Gross amounts offset	(9)	(28)
Derivative liability, net amounts recognized in the balance sheets	271	125
Collateral already posted, assets, aggregate fair value	36
Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	17	10
Derivative liability, gross amount recognized	2	4
Derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	16	9
Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	4
Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	1
Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	497	201
Derivative liability, gross amount recognized	7	36
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	381	129
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	30
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	116	72
Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	6	6
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	50	27
Derivative liability, gross amount recognized	271	113
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	28	7
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	5
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	5	1
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	17	19
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	3	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	136	29
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	59	39
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	71	40
ALABAMA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(2)	(5)
Derivative asset, net amounts recognized in the balance sheets	126	50
Derivative liability, Gross amounts offset	(2)	(5)
Derivative liability, net amounts recognized in the balance sheets	0	6
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	128	55
Derivative liability, gross amount recognized	2	11
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	87	30
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	9
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	41	25
ALABAMA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	2
GEORGIA POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	191	75
Derivative asset, Gross amounts offset	(1)	(8)
Derivative asset, net amounts recognized in the balance sheets	190	67
Derivative liability, gross amount recognized	1	8
Derivative liability, Gross amounts offset	(1)	(8)
Derivative liability, net amounts recognized in the balance sheets	0	0
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	179	75
Derivative liability, gross amount recognized	1	8
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	150	54
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	6
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	29	21
GEORGIA POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	2
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	12	0
Derivative liability, gross amount recognized	0	0
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	12	0
GEORGIA POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
MISSISSIPPI POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, Gross amounts offset	(2)	(4)
Derivative asset, net amounts recognized in the balance sheets	136	52
Derivative liability, Gross amounts offset	(2)	(4)
Derivative liability, net amounts recognized in the balance sheets	0	1
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	138	56
Derivative liability, gross amount recognized	2	5
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	94	30
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	3
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	44	26
MISSISSIPPI POWER CO | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	2
SOUTHERN POWER CO
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	8	4
Derivative asset, Gross amounts offset	0	0
Derivative asset, net amounts recognized in the balance sheets	8	4
Derivative liability, gross amount recognized	43	16
Derivative liability, Gross amounts offset	0	0
Derivative liability, net amounts recognized in the balance sheets	43	16
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	2	1
SOUTHERN POWER CO | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	6	3
Derivative liability, gross amount recognized	43	16
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	3	2
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	3	1
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	35	16
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN POWER CO | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Foreign currency derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	8	0
SOUTHERN Co GAS
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	94	35
Derivative asset, Gross amounts offset	(40)	(8)
Derivative asset, net amounts recognized in the balance sheets	54	27
Derivative liability, gross amount recognized	40	27
Derivative liability, Gross amounts offset	(4)	(11)
Derivative liability, net amounts recognized in the balance sheets	36	16
Collateral already posted, assets, aggregate fair value	36	3
SOUTHERN Co GAS | Derivatives not designated as hedging instruments
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	15	9
Derivative liability, gross amount recognized	1	4
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	14	8
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	4
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	1	1
SOUTHERN Co GAS | Derivatives not designated as hedging instruments | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	52	15
Derivative liability, gross amount recognized	1	12
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	49	15
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	1	12
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	3	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments for regulatory purposes | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	27	11
Derivative liability, gross amount recognized	38	11
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	25	5
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other current liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	2	5
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	2	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Energy-related derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Assets from risk management activities
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	6
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred charges and assets
Derivatives, Fair Value [Line Items]
Derivative asset, gross amount recognized	0	0
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Other deferred credits and liabilities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	36	6
SOUTHERN Co GAS | Derivatives designated as hedging instruments in cash flow and fair value hedges | Derivatives designated as hedging instruments for regulatory purposes | Interest rate derivatives | Liabilities from risk management activities
Derivatives, Fair Value [Line Items]
Derivative liability, gross amount recognized	$ 0	$ 0

XML

Derivatives - Schedule of Pre-tax Effects of Unrealized Derivative Gains (Losses) (Details) - Energy-related derivatives - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	$ 464	$ 155
Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	353	107
Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	111	65
Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)		(17)
ALABAMA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	126	44
ALABAMA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	87	28
ALABAMA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	39	22
ALABAMA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)		(6)
GEORGIA POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	178	67
GEORGIA POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	150	48
GEORGIA POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	28	19
GEORGIA POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)		0
MISSISSIPPI POWER CO
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	136	51
MISSISSIPPI POWER CO | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	94	27
MISSISSIPPI POWER CO | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	42	24
MISSISSIPPI POWER CO | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)		0
SOUTHERN Co GAS
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	24	(7)
SOUTHERN Co GAS | Other regulatory liabilities, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	22	4
SOUTHERN Co GAS | Other regulatory liabilities, deferred
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)	$ 2	0
SOUTHERN Co GAS | Other regulatory assets, current
Derivative Instruments, Gain (Loss) [Line Items]
Total energy-related derivative gains (losses)		$ (11)

XML

Derivatives - Schedule of Pre-Tax Effects of Hedging on AOCI (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	$ 27	$ (39)
Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	42	5
Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	9	3
Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(28)	(47)
Fair Value Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	4	0
GEORGIA POWER CO | Cash Flow Hedging | Interest rate derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	12	0
Southern Power
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(23)	(43)
Southern Power | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	5	4
Southern Power | Cash Flow Hedging | Foreign currency derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	(28)	(47)
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss) Recognized in OCI on Derivative	$ 37	$ 1

XML

Derivatives - Schedule of Pre-Tax Effects of Cash Flow and Fair Value Hedging on Income (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Derivative [Line Items]
Depreciation and amortization	$ 892	$ 871
Total interest expense, net of amounts capitalized	(462)	(450)
Total other income (expense), net	145	58
Natural gas
Derivative [Line Items]
Total cost of sales	1,095	583
Other Income (Expense)
Derivative [Line Items]
Amount excluded from effectiveness testing recognized in earnings	(4)	0
Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	9	(3)
Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	2	3
Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(7)	(7)
Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(6)	(6)
Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(25)	(60)
Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(123)	(10)
Fair Value Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(24)	0
SOUTHERN POWER CO
Derivative [Line Items]
Depreciation and amortization	120	119
Total interest expense, net of amounts capitalized	(37)	(38)
Total other income (expense), net	2	7
SOUTHERN POWER CO | Cash Flow Hedging | Energy-related derivatives | Depreciation and Amortization
Derivative [Line Items]
Gain (loss) on hedges	2	3
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(6)	(6)
SOUTHERN POWER CO | Cash Flow Hedging | Foreign currency derivatives | Other Income (Expense)
Derivative [Line Items]
Gain (loss) on hedges	(25)	(60)
SOUTHERN Co GAS
Derivative [Line Items]
Depreciation and amortization	137	130
Total interest expense, net of amounts capitalized	(61)	(60)
Total other income (expense), net	16	(63)
SOUTHERN Co GAS | Natural gas
Derivative [Line Items]
Total cost of sales	1,095	583
SOUTHERN Co GAS | Cash Flow Hedging | Energy-related derivatives | Cost of Sales
Derivative [Line Items]
Gain (loss) on hedges	9	0
SOUTHERN Co GAS | Cash Flow Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	(1)	0
SOUTHERN Co GAS | Fair Value Hedging | Interest rate derivatives | Interest Expense
Derivative [Line Items]
Gain (loss) on hedges	$ (36)	$ 0

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Derivatives - Schedule of Cumulative Basis Adjustments for Fair Value Hedges (Details) - Fair Value Hedging - Long-term debt - USD ($) $ in Millions	Mar. 31, 2022	Dec. 31, 2021
Derivative [Line Items]
Carrying Amount of the Hedged Item	$ (3,136)	$ (3,280)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	126	9
SOUTHERN Co GAS
Derivative [Line Items]
Carrying Amount of the Hedged Item	(459)	(493)
Cumulative Amount of Fair Value Hedging Adjustment included in Carrying Amount of the Hedged Item	$ 37	$ 2

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Derivatives - Schedule of Pre-tax Effect of Interest Rate and Energy Related Derivatives on Income (Details) - Derivatives not designated as hedging instruments - Energy-related derivatives - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 23	$ (10)
Natural gas revenues
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	2	(17)
Cost of natural gas
Derivative Instruments, Gain (Loss) [Line Items]
Derivative instruments not designated as hedging instruments, gain (loss), net	$ 21	$ 7

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Acquisitions and Dispositions - Southern Power Narrative (Details) - SOUTHERN POWER CO - MW	1 Months Ended		3 Months Ended	12 Months Ended
	Mar. 31, 2022	Feb. 28, 2022	Mar. 31, 2022	Dec. 31, 2021
Tranquillity Solar Storage
Business Acquisition [Line Items]
Nameplate capacity placed in service (in MWs)	40		40	32
Garland Solar Storage
Business Acquisition [Line Items]
Nameplate capacity placed in service (in MWs)		15	15	73

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Acquisitions and Dispositions - Schedule of Construction Projects (Details) - SOUTHERN POWER CO - MW	1 Months Ended		3 Months Ended	4 Months Ended	6 Months Ended	12 Months Ended
	Mar. 31, 2022	Feb. 28, 2022	Mar. 31, 2022	Dec. 31, 2021	Mar. 31, 2022	Dec. 31, 2021
Garland Solar Storage
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)	88		88		88
PPA Contract Period				20 years
Nameplate capacity placed in service (in MWs)		15	15			73
Tranquillity Solar Storage
Business Acquisition [Line Items]
Approximate Nameplate Capacity (MW)	72		72		72
PPA Contract Period					20 years
Nameplate capacity placed in service (in MWs)	40		40			32

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Segment and Related Information - Narrative (Details) $ in Millions	3 Months Ended
	Mar. 31, 2022 USD ($) state segment	Mar. 31, 2021 USD ($)
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	3
Operating revenues	$ 6,258	$ 6,900
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	413	296
SOUTHERN POWER CO | Traditional Electric Operating Companies | Wholesale revenues, affiliates
Segment Reporting Information [Line Items]
Operating revenues	$ 105	81
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Number of states in which entity operates | state	4
Operating revenues	$ 2,043	2,976
Number of reportable segments | segment	3
SOUTHERN Co GAS | SOUTHERN POWER CO | Natural gas
Segment Reporting Information [Line Items]
Operating revenues		$ 12
Southern Natural Gas Company, LLC | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	50.00%
Dalton Pipeline | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	50.00%
PennEast Pipeline | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Ownership percentage, equity method investment	20.00%

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Segment and Related Information - Schedule of Financial Data for Business Segments (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021	Dec. 31, 2021
Segment Reporting Information [Line Items]
Operating revenues	$ 6,648	$ 5,910
Net income	1,032	1,135
Goodwill	5,280		$ 5,280
Total assets	128,639		127,534
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Gain on sale	20	41
GEORGIA POWER CO
Segment Reporting Information [Line Items]
Operating revenues	2,208	1,970
Total assets	49,206		48,461
Estimated loss on Plant Vogtle Units 3 and 4	0	48
Estimated loss on Plant Vogtle Units 3 and 4, net of tax		36
SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	539	440
Segment net income (loss)	72	97
Total assets	13,766		13,390
Gain on sale	2	39
SOUTHERN POWER CO | Wind Generating Facility
Segment Reporting Information [Line Items]
Gain on sale		37
Gain on sale, net of tax		28
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	2,058	1,694
Segment net income (loss)	319	398
Goodwill	5,015		5,015
Total assets	23,377		23,560
Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	4,509	4,117
SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	2,058	1,694
Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	4,034		4,034
Wholesale Gas Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues		298
Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Goodwill	981		981
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	2,054	1,701
Segment net income (loss)	309	394
Total assets	24,147		23,971
Operating Segments | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	4,509	4,117
Net income	846	853
Goodwill	2		2
Total assets	103,599		101,774
Operating Segments | Traditional Electric Operating Companies
Segment Reporting Information [Line Items]
Operating revenues	4,191	3,764
Net income	774	756
Goodwill	0		0
Total assets	90,460		89,051
Operating Segments | SOUTHERN POWER CO
Segment Reporting Information [Line Items]
Operating revenues	539	440
Net income	72	97
Goodwill	2		2
Total assets	13,766		13,390
Operating Segments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	2,058	1,694
Net income	319	398
Goodwill	5,015		5,015
Total assets	23,377		23,560
Operating Segments | Gas distribution operations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	1,803	1,200
Segment net income (loss)	214	183
Total assets	21,034		20,917
Operating Segments | Gas Pipeline Investments | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	8	8
Segment net income (loss)	29	29
Total assets	1,473		1,467
Operating Segments | Wholesale Gas Services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	0	298
Segment net income (loss)	0	126
Total assets	0		31
Operating Segments | Gas marketing services | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	243	195
Segment net income (loss)	66	56
Total assets	1,640		1,556
Operating Segments | All Other
Segment Reporting Information [Line Items]
Operating revenues	123	134
Net income	(125)	(108)
Goodwill	263		263
Total assets	4,236		2,975
Operating Segments | All Other | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	16	7
Segment net income (loss)	10	4
Total assets	12,017		12,114
Eliminations
Segment Reporting Information [Line Items]
Operating revenues	(42)	(35)
Net income	(8)	(8)
Goodwill	0		0
Total assets	(2,573)		(775)
Eliminations | SOUTHERN Co GAS
Segment Reporting Information [Line Items]
Operating revenues	(12)	(14)
Segment net income (loss)	0	0
Total assets	(12,787)		(12,525)
Eliminations | Electric Utilities
Segment Reporting Information [Line Items]
Operating revenues	(221)	(87)
Net income	0	$ 0
Goodwill	0		0
Total assets	$ (627)		$ (667)

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Segment and Related Information - Schedule of Financial Data for Products and Services (Details) - USD ($) $ in Millions	3 Months Ended
	Mar. 31, 2022	Mar. 31, 2021
Concentration Risk [Line Items]
Operating revenues	$ 6,648	$ 5,910
Retail
Concentration Risk [Line Items]
Operating revenues	3,613	3,342
Wholesale Electric
Concentration Risk [Line Items]
Operating revenues	664	545
Other
Concentration Risk [Line Items]
Operating revenues	177	170
Other revenues
Concentration Risk [Line Items]
Operating revenues	136	159
Less Gross Gas Costs	69	82
Natural Gas
Concentration Risk [Line Items]
Operating revenues	2,058	1,694
Electric Utilities
Concentration Risk [Line Items]
Operating revenues	4,509	4,117
Electric Utilities | Retail
Concentration Risk [Line Items]
Operating revenues	3,613	3,342
Electric Utilities | Wholesale Electric
Concentration Risk [Line Items]
Operating revenues	664	545
Electric Utilities | Other Revenue
Concentration Risk [Line Items]
Operating revenues	232	230
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	2,058	1,694
Southern Company Gas' Revenues | Gas Distribution Operations
Concentration Risk [Line Items]
Operating revenues	1,791	1,192
Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues	0	298
Southern Company Gas' Revenues | Gas marketing services
Concentration Risk [Line Items]
Operating revenues	243	195
Southern Company Gas' Revenues | Other
Concentration Risk [Line Items]
Operating revenues	24	9
Southern Company Gas' Revenues
Concentration Risk [Line Items]
Operating revenues	$ 2,058	1,694
Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		298
Less Gross Gas Costs		2,353
Third Party Gross Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		2,588
Intercompany Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		63
Total Gross Revenues | Southern Company Gas' Revenues | Wholesale Gas Services
Concentration Risk [Line Items]
Operating revenues		$ 2,651